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178-042
STATE OF ALASKA -" ALASKA O1,_ AND GAS CONSERVATION C )MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: x GAS: SUSPENDED: ABANDONED: x SERVICE: 2. Name of Operator 7. Permit Number Unocal ~ 78-042 3. Address 8. APl Number P. O. Box 196247 Anchorage, AK 99519-6247~......_~,_ ~_ _~ 50- 733-20116-02 4. Location of well at surface~~ C0'~PL~T~ ~ ,!~r'~'~~ 9. Unit or Lease Name 1874' FSL and 1386' FEL Sec. 29, T9N, R13 W, SM Trading Bay Unit At Top Producing Interval (12,962' md) i 10. Well Number 565' FSL and 1736' FEL, Sec. 33, T9N, R13W, SM i G-12RD2 At Total Depth (13800' md) 11. Field and Pool 180' FSL and 1301' FEL Sec. 33, T9N, R13W, SM McArthur River/Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 103' RT above MSL ADL-17594 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 5/21/1978 6/12/1978I 5/13~2002 125 feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 13800'/10097' 8301 '/6013' Yes: No:I N/A feet MD N/A 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" 1" wt 0' 369' Drive Drive 17-3~4" .312" wt 0' 602' 22" 775 sxs 13-3/8" 61# K-55 0' 6013' 18" 2525 sxs 9-5/8" 40 -47# N-80/P-110 0' 10257' 12-1/4" Window 7" 29~ N-80 9734' 13782' 8-1/2" 700 sxs 24. Perforations open to Production (MD+'rVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" See Attached Schematic 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD => Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE 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. 31. LIST OF ATTACHMENTS Daily Report Summary, Well Schen tafl~,a,~,d Survey Report. 32. I hereby certify that~JjJ~.~. ~:~goin~e anl:l correct to the best of my knowledge Si ~,~ Title ~I;~';~..,1 ~ ~, Date c~ [-~-~ f INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is 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. Form 10-407 Item 28: If no cores taken, indicate "none". Grayling Well G-12RD2 Abadonment Daily Summary Unocal Alaska Drilling Daily Summary Report G-12RD2 Abadonment 5~08~02 to 5/13/02 5/08/02 Accept rig from leg move. 5/09/02 N/U BOP and test to 3000 psi high/ 250 psi Iow. P/U on tubing 85K over block weight to put tubing into tension. RIH w/ jet cutter and cut tubing at 8,364'. Circulate thru tubing cut with water. 5/10/02 POOH with cut 3-1/2" tubing. Change out top pipe rams from 3-1/2" to 5" and test to 4000 psi high/250 psi Iow. M/U clean out BH^. 5/11/02 P/U 5" drill pipe. 5/12/02 R/U Schlumberger. RIH with Baker Mod. K-1 cement retainer. Set retainer at 8301'. M/U cement stinger and RIH to top of cement retainer. Pressure test retainer and casing to 1500 psi for 15 minutes with no bleed off. Cement thru retainer with 61 bbls of 15.8 ppg cement. Sting out and circulate well clean. POOH with cement stinger. 5/13/02 Continue out of hole with cement stinger. N/D BOPE. Release Rig. UNOCAL Trading Bay Unit Well # G-12RD2 Actual Abandonment Orig RKB to TBG Head '- 43.2' Tree connection: 8301' 9734' CASING AND TUBING DETAIL MD SIZE WT GRADE CONN ID TOP 26" 1/2" Wall Surf. 17-3/4" .312 wall Weld Surf. 13-3/8" 61 K-55 Butt 12.515 Surf. 9-5/8" 47 P-110 Seal Lock 8.681 Surf. 9-5/8" 40# N-80 Seal Lock 8.835 73 9-5/8" 43.5# N-80 Seal Lock 8.755 6251' DV Collar ....................................................................... 6939' 9-5/8" 43.5# N-80 Seal Lock 8.755 694 I' 9-5/8" 47 N-80 Seal Lock 8.681 9276.06' 7" 29 N-80 Butt 6.184 9734' Tubing: 3-1/2" 9.3 L-80, EUE8rd 2.992 8306' Mod MD BTM. 369' 602' 6013' 73' 6252' 6939' 6941' 9276' 10,257' 13,782' 12,154' TVI) BTM. 10,575 CMT Driven 775 sx 2525 SX 800 sx 10,257 12,882' 4a JEWELRY DETAIL NO. Depth ID item 1 8301' 2 8364' 3 12,072' 4 12,119' 4a 12,151' 12,154' 5 12,882' 6 12,885' 7 12,894' 8 12,895' 9 12,925' btm 12,926' 9-5/8" Cement Retainer Cut 3-1/2" Tubing 3.25 Baker SAB Hyd permanent pkr with anchor 2.813 X nipple 2.781 Baker Model "E" Hydro-trip sub w/mule shoe Note: 2.72" blind box was needed to beat thru hydrotrip sub on 9/11/98 2.992 Baker 8rd Wireline Muleshoe 4.00 Baker Model "FB- 1" Pkr 4.00 Seal Bore Ext. Cross Over 2.75 Otis "X" Profile Nipple 2.99 WLEG Bad csg 13,205' to 13,220' Taper mill ran on prior to acid stim. showed 100% of water going out this B-1 B-4 ETD = 13,678' TD = 3,800' RT to MLLW ELEV = I 13' MAX ANGLE = 59.30° @ 2500' KOP @ 10,262' PERFORATION DATA Accum Last Zone Top Btm Amt SPF Perf Date Present Condition G-2 12305 12339 34 6 9/14198 Open G-3 12362 12372 t0 6 9114/98 Open G-3 12378 12388 10 6 9113198 Open G-3 12403 t2413 10 6 9113198 Open G-4 12480 12550 70 6 91t3198 Open G.4 '12560 12575 15 6 91t3198 Open G-5 12687 12717 30 6 9112/98 Open G-5 12732 12752 20 6 9112/98 Open __ -- 12,972' 12,974' 4' 4 6/20/78 Sqz Perfs B-1 12,975' 13,005' 30' 12 5/25/87 Open fi Injection _ B-1 12,978' 13,008' 30' 4 1/28/98 Open fi Injection -- 13,014' 13,016' 2' 4 6/19/78 Sqz Perfs B-4 13,265' 13,390' 125' 12 5/25/87 Open fi Injection 13,410' 13,412' 2' 4 6/19/78 Sqz Perfs _ G-12 RD2 Actual Abandonment Schematic.doc DRAWN BY: LWB REVISED: 08/27/02 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL( Larry W. Buster Advising Drilling Engineer August 23, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Commissioner CammyTaylor Re; Well Completion Report (Form 407a) Trading Bay Unit/McArthur River Field Grayling Platform, Well G-12RD2 Abandonment Commissioner Taylor: Enclosed for your review is the Well Abandonment Report for the Grayling Well G- 12RD2. This existing Hemlock completion was abandoned and the wellbore was utilized to re- drill the G-12RD3 Well. The G-12RD3 final well report will be submitted under separate cover. If there are any questions, please contact myself at 263-7804. ~Larry W.Buster - ~ Advising Drilling Engineer Unocal Alaska LB/s Re: TBU G-12RD2 Plugging for Sidetrack Subject: Re: TBU G-12RD2 Plugging for Sidetrack Date: Fri, 04 Oct 2002 15:59:19-0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Buster, Larry W" <lbuster@unocal.com> Larry, Thanks for your reply to the G-12RD2 matter. I appreciate your having brought this matter to the attention of the other engineers and the supervisors. When the Commission gives approval for an operation, it is our expectation that the work will ultimately be accomplished according to the plan that was presented unless additional information is provided to the Commission indicating that the work cannot be accomplished as planned. I recall a number of discussions I have had with the various engineers over there when a change was requested due to encountering junk, fishing not proceeding as planned or an injection rate not being achievable. Often times the notice and subsequent approval seem to be handled as a matter of routine, but that necessary exchange satisfies 20 AAC 25.507, "Change of an Approved Program". I look forward to continued a good working relationships with Unocal engineers and supervisors and timely notice when a change to an approved program is necessary. Tom Maunder, PE c~_~.,,,~.~,r,.~- o~:~\,,.~r,¢~ ,,x.~,Cj.%~ %~~ AOGCC ~ O ~ ~ ~, ~ ~ ~ ~ ~~ "Buster, Larw W" wrote: ~k~ ~ ~ O ~ ~ ~ ~~ Tom, '% First, I would like to apologize for my slow response to your request. I have been working to come up with an accurate summary of this event. There wasn't any mechanical problems with the surface equipment or establishing injection into the well (both before and during the squeeze). The program stated we required 87 bbls to be pumped. However, the actual useable volume made available to pump was only 61 bbls. This was due to two factors. First, this was the usable volume available on the rig at the time the squeeze was performed and Second, this volume was deemed sufficient by Unocal Supervisors to perform the required squeeze work within the required guidelines as they understood them. Obviously, we did not complied with the scope of work as outlined within the 403, have been dilatory in notify the AOGCC of the final fora request of variance to the 403. I don't have any excuse for this. I understand that events of this nature impact the trust and respect important in the working relationship between Unocal and the AOGCC. I have pointed this out in our Weekly Operations Meetings in order to heighten the awareness of everyone within the Unocal Drilling Department. In an effort to mitigate events of this nature from happening again, I will insist that that all Future Unocal Work Programs have the statement "Notify the AOGCC of any planned variations to the approved scope of work as outlined in the approved notice(s) prior to undertaking that work". This, along with attaching a copy of the complete approved sundry/drilling notice, should impress upon Foreman, Engineers and Superintendents of the importance in following the agreed upon scope of work and the importance of notifying you when variations occur. In summary, we pumped less then we should have and didn't notify you. From my part, I am embarrassed in having to write this letter and will work hard to make sure it doesn't happen again. Let me know of anything else you may require from me in regards to this matter. 1 of 2 10/8/2002 11:37 AM Re: TBU G-12RD2 Plugging for Sidetrack Regards, Larry Buster Drilling Engineer ..... Original Message ..... From: Tom Maunder [ma#to:tom maunder~,admin, state, ak. us! Sent: Sunday, September 01, 2002 4:36 PM To: Larry Buster Subject: TBU G-12RD2 Plugging for Sidetrack Larry, I am reviewing the 407 you submitted regarding the cement plugging of this weft in preparation to sidetrack. When the 403 was approved, the calculated cement volume to plug the casing and tubing spaces to the bottom perforations was some 87 bbls. The report you submitted indicates that only 61 bbls was pumped. Were there any problems encountered pumping the cement?? The report doesn't indicate any difficulties. I have checked my diary and emails and I don't have any notes regarding any proposed changes. I'd appreciate your following up on this matter. Thanks. Tom Maunder, PE AOGCC Tom Maunder <tom maunder@admin.state.ak, us> i sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 10/8/2002 11:37 AM Re: TBU G-12RD2 Plugging for Sidetrack Subject: Re: TBU G.12RD2 Plugging for Sidetrack Date: Wed, 02 Oct 2002 15:24:59 -0800 From: Tom Maunder <tom_maunder@admin,state.ak.us> To: "Buster, Larry W" <lbuster@unocal.com> Larry, I was cleaning up some paperwork. Did you ever find the answers to my questions?? This is the last message I show we exchanged. Tom Maunder "Buster, Larry VV" wrote: Tom, You are correct, I need to review the details around this and will get back to you. I believe there was an issue with the cement deliverability while mixing the job, but need to review. ! can't explain why you weren't notified of the volume pumped differing from the 403 stated amount, but fully understand your concern. Again, let me review and I will get back to you. Regards, Larry .... Original Message .... From: Tom Maunder [mai!to;tom__m.aunder~admin~state.ak. us] Sent: Sunday, September 01, 2002 4:36 PM To: Larry Buster Subject: TBU G- 12RD2 Plugging for Sidetrack Larry, I am reviewing the 407 you submitted regarding the cement plugging of this well in preparation to sidetrack. When the 403 was approved, the calculated cement volume to plug the casing and tubing spaces to the bottom perforations was some 87 bbls. The report you submitted indicates that only 61 bbls was pumped. Were there any problems encountered pumping the cement?? The report doesn't indicate any difficulties. I have checked my diary and emails and I don't have any notes regarding any proposed changes. I'd appreciate your following up on this matter. Thanks. Tom Maunder, PE AOGCC Tom Maunder <tom__maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 10/2/2002 3:25 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: x Suspend: Operation shutdown: Re-enter suspended well: , Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 103' RT above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface Grayling Platform, Leg #2, Conductor #37 8. Well number 1,874' FSL & 1,386' FEL of Sec.29, T9N, R13W, SM Grayling G-12RD2 At top of productive interval 12,962' MD 9. Permit number 565' FSL & 1,736' FEL of Sec. 33, T9N, R13W, SM 78-042 At effective depth 13,679' MD 10. APl number 235' FSL & 1,364' FEL of Sec.33, T9N, R13W, SM 50- 733-20116-02 At total depth 13,800' MD 11. Field/Pool 180' FSL & 1,301' FEL of Sec.33, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 13,800 feet Plugs (measured) true vertical 10,110 feet Effective depth: measured 13,679' feet Junk (measured) 13,679' true vertical 10,005' feet Casing Length Size Cemented Measured depth True vertical depth Structural 369' 26" Driven 369' 369' Conductor 602' 17 3/4" 775 sxs 602' 602' Surface 6013' 13-3/8" 2525 sxs 6013' 4237' Intermediate Production 10257' 9-5/8" Window 10257' 7439' Liner 4036' 7" 700 sx 9746' - 13782' 10095' Perforation depth: measured 12,305-12732' (intermittent)12,975'-13,008', 13,265'-13,390' RECE, ~VED true vertical 8960'-9296', 9,488'-9,512', 9,700'-9,800' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, @ 12,926' ~-J~N -1. Packers and SSSV (type and measured depth) Baker SAB Hyd. @ 12,072' & Baker FB-1 @ 12,882' ~iaska 0il & Gas C0~)s. C0mm/ssi0r~ 13. Attachments Description summary of proposal: x Detailed operations program: BOP ske[~H.~'~'~ 14. Estimated date for commencing operation 15. Status of well classification as: 3/15/2002 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: Re-use well for re-drill. 17. I hereby, certify that the.foregoing is true and correct to the best of my knowledge. Sig ne~f,~j~~an Williamson Title: Drilling Manager Date: l/~/(-~/~__,~ ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I1~)~ ,~,"t ~::~:;~ '¥~..~,3¢'~,,,~ IAppr°va,~'~ Plug integrity__ BOP Test ~ Location clearancer-- i . ~.-.-,.,--,,- "(~)~ Mechanical Integrity Test Subsequent form required 10- I.,~.l~"~, Original Signed By Approved by order of the Commissioner ~aiTl~¥ 0echsli Commissioner Date ORIGINAL Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCAL( Grayling G-12RD2 Abandonment Proposal Description Summary of Proposed G-12RD2 Abandonment 1. Move in rig; kill well with 8.5 ppg FIW. ND tree, NU BOPE. 2. Test BOPE to 3000 .psi. ~3'¢¢"~ 3. Cut 3-1/2" tubing 8,250'. 4. Pull and lay down 3-1/2" tubing. 5. Run 9-5/8" tri-mill cleanout assembly to remaining tubing stub at 8,250'. 6. RIH with 9-5/8" cement retainer on drill pipe. 7. Run Gamma Ray correlation log through drill pipe and set retainer at 8,200'. . Pump 524 sxs (81.6 bbls) cement through retainer to abandon G-Zone and Hemlock intervals. 8200-8250 50 9-5/8~eg~,~' 8250-12151 3901 ~,~" tbg 12151 - 12732 58,,1.-'"- 7" csg 12731-12926 ~-"'I~5 3-1/2" tbg 564 7" csg 81.6 bbls = 524 sxs (1.'i5 yield cement) Cement Volumes from proposed retainer at 8,200' to 100' below Hemlock Perforations at 13,390': Depth Length Area Ca pa ci~.~-,--'-'"'~ Volume ft ft ..-.--15bl/ft 0.0732 0.0087 0.0371 0.0087 0.0371 9. Unsting from retainer at 8,200' and POOH with drill pipe. bbl 3.6 33.9 21.5 1.7 20.9 81.6 10. Pressure test retainer to 1500 psi. G 12 RD2 Abandonment Proc.doc 1/9/2002 Subject: G- 12RD2 Abandonment Changes Date: Thu, 17 Jan 2002 18:22:15 -0800 From: "Buster, Larry W-Alaska" <lbuster~tmocal. corn~ To: "Tom Maunder (E-mail)" <tom_maunder~admin. state, ak.us~ Dear Tom, As per our discussion, I would like to submit the following changes for the proposed G-12RD2 Abanonment Procedure: 8. Pump 426 sxs (87.2 bbls) cement through retainer to abandon G-Zone and Hemlock intervals. Cement Volumes t~om proposed retainer at 8,200' to 100' below Hemlock Perforations at 13,390': Depth Length Area Capacity fi fi bbl/fi 8200-8250 50 9-5/8" csg 0.0732 8250-12151 3901 3-1/2"tbg 0.0087 12151-12882 731 7" csg 0.0371 12882-12926 195 3-1/2" tbg 0.0087 12926-13490 564 7" csg 0.0371 Volume bbl 3.6 33.9 27.1 1.7 20.9 Total 87.2 87.2 bbls = 426 sxs (1.15 yield cement) Regards, Larry W. Buster Drilling Engineer Unocal Alaska (907) 263-7804 - Office (907) 263-7884 - Fax (907) 351-6730- Mob. UNOCALe Trading Bay Unit Well # G-12RD2 Proposed Abandonment Orig RKB to TBG Head = 43.2' Tree connection: 8200' 9734' CASING AND TUBING DETAIL SIZE WT GRADE MD MD TVD CONN ID TOP BTM. BTM. 26" 1/2" Wall Surf. 17-3/4" .312 wall Weld Surf. 13-3/8" 61 K-55 Butt 12.515 Surf. 9-5/8" 47 P-110 Seal Lock 8.681 Surf. 9-5/8" 40# N-80 Seal Lock 8.835 73 9-5/8" 43.5# N-80 Seal Lock 8.755 6251' DV Collar ....................................................................... 6939' 9-5/8" 43.5# N-80 Seal Lock 8.755 6941' 9-5/8" 47 N-80 Seal Lock 8.681 9276.06' 7" 29 N-80 Butt 6.184 9734' Tubing: 3-1/2" 9.3 L-80, EUESrd 2.992 9750' Mod 369' 602' 6013' 73' 6252' 6939' 6941' 9276' 10,257' 13,782' 12,154' 10,575 CMT Driven 775 sx 2525 sx 800 sx 12,882' 4a NO. Depth 1 8200' 2 8250' 3 12,072' 4 12,119' 4a 12,151' 12,154' 5 12,882' 6 12,885' 7 12,894' 8 12,895' 9 12,925' btm 12,926' JEWELRY DETAIL 1D Item 9-5/8" Cement Retainer Cut 3-1/2" Tubing 3.25 Baker SAB Hyd permanent pkr with anchor 2.813 X nipple 2.781 Baker Model "E" Hydro4rip sub w/mule shoe Note: 2.72" blind box was needed to beat thru hydrotrip sub on 9/11/98 2.992 Baker 8rd Wireline Muleshoe 4.00 Baker Model "FB- 1" Pkr 4.00 Seal Bore Ext. Cross Over 2.75 Otis "X" Profile Nipple 2.99 WLEG Bad csg 13,205' to 13,220' Taper mill ran on 5/21/87 showed undersized csg. PL ran on 5/26/87 prior to acid stim. showed 100% of water going out this interval B-1 B-4 PERFORATION DATA Accum Last Zone Top Btm Amt SPF Perf Date Present Condition G-2 12305 12339 34 6 9114198 Open G-3 12362 12372 10 6 9114198 Open G-3 12378 12388 10 6 9113198 Open G-3 12403 12413 10 6 9113198 i Open G4 12480 12550 70 6 9113198 Open G4 t2560 12575 15 6 9113198 Open G-5 12687 12717 30 6 9112/98 Open G-5 12732 12752 20 6 9112/98 Open 12,972' 12,974' 4' 4 6/20/78 Sqz Perfs B-1 12,975' 13,005° 30' 12 5/25/87 Open f/Injection B-1 12,978' 13,008' 30' 4 1/28/98 Open f/Injection 13,014' 13,016' 2' 4 6/19/78 Sqz Perfs B-4 13,265' 13,390' 125' 12 5/25/87 Open f/Injection 13,410' 13,412' 2' 4 6/19/78 Sqz Perfs -.. ETD -- 13,678' TD -- 3,800' RT to MLLW ELEV = 03' MAX ANGLE = 59.30° (~ 2500' KO P @ 10,262' G-12 RD2 Abandonment Schematic.doc DRAWN BY: TAB REVISED: 01/09/02 UNOCAL ) Orig RKB to TBG Head = 43.2' Tree connection: 9734' 10,257 12,882' Addedd G-2 thru G-5 perfs _-- 12305'- 12752' 3 Bad csg 13,205' to 13,220' Taper mill ran on 5/21/87 showed undersized csg. PL ran on 5/26/87 prior to acid stim. showed 100% of water going out this interval B-4 ETD = 13,678' TD = 13,800' RT to MLLW ELEV = 103' MAX ANGLE = 59.30° (~ 2500' KOP @ 10,262' Trading Bay Unit Well tt G-12RD2 Completed 3/31/98, Perfed 9/12-14/98 SIZE WT GRADE CASING AND TUBING DETAIL MD MD TVD CONN ID TOP BTM. BTM. 26" 1/2" Wall Surf.. 369' 17-3/4" .312 wall Weld Surfi 602' 13-3/8" 61 K-55 Butt 12.515 Surf. 6013' 9-5/8" 47 P-110 Seal Lock 8.681 Surf. 73' 9-5/8" 40# N-80 Seal Lock 8.835 73 6252' 9-5/8" 43.5# N-80 Seal Lock 8.755 6251' 6939' DV Collar .......................................................................6939' 694 I' 9-5/8" 43.5# N-80 Seal Lock 8.755 6941' 9276' 9-5/8" 47 N-80 Seal Lock 8.681 9276.06' (i) 10,257' 7" 29 N-80 Butt 6.184 9734' 13,782' Tubing: 3-1/2" 9.3 L-80, EUE8rd 2.992 0' 12,154' 10,575 , JEWELRY DETAIL NO. Depth ID Item 43.2' 1 12,072' 2 : 12,119' 2a 12,151' 12,154' 3 12,882' 4 12,885' 5 12,894' 6 12,895' 7 12,925' btm 12,926' 3-1/2" CIW Tubing Hanger, 8rd top and butt bottom 3-1/2" 8rd mod x 3-1/2" butt AB mod xover 3.25 Baker SAB Hyd permanent pkr with anchor 2.813 X nipple 2.781 Baker Model "E" Hydro-trip sub w/mule shoe Note: 2.72" blind box was needed to beat thru hydrotrip sub on 9/11/98 2.992 Baker 8rd Wireline Muleshoe 4.00 Baker Model "FB- !" Pkr 4.00 Seal Bore Ext. Cross Over 2.75 Otis "X" Profile Nipple 2.99 WLEG FISH Milled up packer 5/21/87 STIMULATIONS Acidize B-1 w/24 bbls ofHCL & 75 bbls of mud acid 5/28/87 SLICKLINE WORK Tagged fill w/2.5" GR 1995 13,679' 13,423' PERFORATION DATA Accum Last Zone Top Btm Amt SPF Perf Date Present Condition G-2 12305 12339 34 6 9114/98 Open G-3 12362 12372 10 6 9/14198 Open G-3 12378 12388 10 6 9/13/98 Open G-3 12403 12413 10 6 9113198 Open G-4 12480 12550 70 6 9113198 Open G-4 12560 12575 15 6 9113/98 Open G-5 12687 12717 30 6 9112198 Open G-5 12732 12752 20 6 9112/98 Open 12,972' 12,974' 4' 4 6/20/78 Sqz Perfs B-1 12,975' 13,005' 30' 12 5/25/87 Open f/Injection B-1 12,978' 13,008' 30' 4 1/28/98 Open f/Injection 13,014' 13,016' 2' 4 6/19/78 Sqz Perfs B-4 13,265' 13,390' 125' 12 5/25/87 Open f/Injection 13,410' 13,412' 2' 4 6/19/78 Sqz Perfs CMT Driven 775 sx 2525 sx 800 sx DRAWN BY: TAB REVISED: 01/09/02 UNOCALe Grayling G-12RD2 Abandonment Proposal Grayling G-12RD2 Summary of Abandonment Proposal Well G-12RD2 is currently a shut-in Hemlock and G-Zone water injector. The plan is to abandon the existing Hemlock and G-Zone intervals. We would then mill a window in the existing 9-5/8" casing from which to drill the planned well G-12RD3 to the Hemlock Formation. This Application Form 403 covers the preliminary abandonment operations of G-12RD2, while a separate Application Form 401 will be submitted later for G-12RD3. Based on reservoir pressure data, 8.5 ppg filtered inlet water will be sufficient for use as the abandonment fluid. There will be LCM available if excessive fluid loss to the formation is encountered. The existing 3-1/2" tubing will be cut and pulled from +/-8,250'. A 9-5~8" cement retainer will then be set at +/-8,200' and cement will be placed from below the retainer to the B-4 Sand Perforations at 13,390'. A variance from 20 AAC 25.112 (c)(1)(D)is requested due to the retainer being more than 500' above the perforations. This request is due to the economic hardship associated with attempting to remove the existing production packers. The abandonment cement should pumpable through the remaining and down into the existing perforations. The calculated cement volume assumes a cement volume to fill from 100' below the lowest open perforations to the proposed cement retainer at +/- 8,200'. The sidetrack operations for G-12RD3 will commence with a whipstock placed on top of the cement retainer at 8,200'. Possible Abandonment Hazards: Lost Circulation Zones: None Low Pressure Zones: None Over Pressure Zones: None G 12 RD2 Abandonment Proc.doc 1/9/2002 3" KILL UNE WITH TWO 3" 5U, VALVES KILL L/NE FROM MUD lamp & CEMENT UNIT , NIPPLE ...... ooo ANNULAR [, I ~ FLOWLINE l PIPE RAMS , ,, · BLIND RAMS PIPE RAMS ), 13-5,/a" 5M FLANGE '" / DOUE1LE GATE SM / L.__[ 13-5/8" 5M FLANGE _' _.t4." CHOKE LINE WrT'H ONE REMOTE &: I ,~NUAL 4" 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD ORAWIN¢) RISER , f fL · ~5-5/a,, ,5,v FLANOS SINGLE GATE 5M 13-5/8" 5M FLANGE 13-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA ,(dba UNOCAL) 10" 5M x 13-5/8" ADAPTER CAMERON 5M SPOOL "~' '~RAWN: APP'I3:OS8 SCALE: NONE o^T~: TO GAS BUSTER /\ AUTOMATIC CHOKE TO OERRICK VENT TO WELL CLEAN TANK /\. 3-I/8" AUTO,UATIC CHOKE UNION VALVES UPSTREAM OF CHOKES ARE 10,000 PSI GATE TYPE VALVES OOWN~~U OF CHOKES ARE 5,000 PSI GATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: OAC APP'O: GS8 SCALE: NO~E o^~s: ~ ~/~s/sg Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) December 28, 2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Request time extension of MIT work for Grayling Platform Well #G-12RD2 RECEIVED Dear Tom: Ala~a Oil & Gas Co~s. Unocal requests a time extension on the MIT work until 12/31/2002. AD~10r'd~ G-12RD2 has tbg/casing communication and is currently shut-in. The plan is to redrill the well to the east flank of the field and complete the well as a producer. We will be submitting another 10-403 in early January 2002 for this work. If the redrill is cancelled, we will complete the previously planned diagniostic work by December 31, 2002. This well will remain shut-in until it is either redrilled or repaired. Attached is a 10-403 for your approval. If you have any questions regarding this, please contact me at 263- 7830. Sincerely, Senior Reservoir Engineer Cook Inlet Waterflood Management Aogcc Grayling G- 12RD2 Variance 12-31-01 .doc 9/18/99 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well Plugging: Time extension X Stimulate: Change approved prograrr Pull tubing: Variance: Perforate: Other: 2. Name of Operate 5. Type of well 6. Datum elevation (DF or KB Union Oil Company of Califonia (UNOCAL Development 103' KB feel 3. Address Exploratory 7. Unit or Property nam~ Stratigraphic: Trading Bay Unil P.O. Box 196247 Anchorage, Alaska 99519-624' Service: 4. Location of well at surface Grayling Platform Leg # 2, Conductor # 37 8. Well number 1,874' FSL, 1,386' FEL, Sec. 29, T9N, R13W, Sb G-12rd2 At top of productive interv~ 12,962' ME: 9. Permit numbe~ 565' FSL, 1,736' FEL, Sec. 33, T9N, R13W, srv 78-042 At effective deptl' 13,679' ME: 10. A);~umbe~ 235' FSL, 1,364' FEL, Sec. 33, T9N, R13W, SlY 5~,-.t~13-20116-02 At total deptf 13,800' MB 11. Fielfl/Poo 180' FSL, 1,301' FEL, Sec. 33, TgN, R13W, SlY McArthur River/"G" & HemlocF 12. Present well condition summar Total depth: measu red 13,800' feel Plugs (measu red', true vertica 10,110' feet Effective depth: measu red 13,679' feel Junk (measu red', 13,679' true vertica 10,005' feel Casing Length Size Cementec Measured deptl' True vertical deptf Structural 369' 26" Driven 369' 369' Conductor 602' 17-3/4" 775 sx 602' 602' Surface 6,013' 13-3/8" 2,525 sx 6,013' 4,237' Inte rmediat~ Production 10,257' 9-5/8" Window 10,257' 7,439' Liner 4,036' 7" 700 sx 9,746'- 13,782 10,095' Perle ratio n depth measu red 12975'- 13008', 13265'- 1339(: true vertica 9488'-9512'; 9700'-9800 Tubing (size, grade, and measured deptl' 3-1/2", 9.2#, N-80 @ 12,925 Packers and SSSV (type and measured deptl' Baker FB-1 Pkr. @ 12,885' 13. Attachement.~ Description summary of proposal X Detailed operations prograrr BOP sketch: 14. Estimated date for commencing operatic 15. Status of well classification as 16. If proposal well verbally approve~ Oil: Gas: Suspended: Name of approver Date approved Service: Water Injector 17. I hereby certify that~.e fo~rego~n~,~e and correct to the best of my knowled! Signed: .......... Title: Senior Reservoir Enginee Date: 12/20/01 v ~ ~- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity.__ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~.~ Original Signed By Approved by order of the Commissioner P.,,m, I~¢~'h,li Commissioner Date RECEIVED Form 10-403 Rev 06/15/88 DEC 8 1 ZOO1 Alaska Oil & Gas Cor~. ~ And~m'a~ SUBMIT IN TRIPLICATE STATE OF ALASKA ALASKA OIL' ,4D GAS CONSERVATION COM,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: SERVICE: X Water Injector "2. Name of Operator ' 7. Permit Number Unocal Oil Company of California (UNOCAL) 78-042 3. Address 8. ~jP~ ~lumber P. O. Box 196247, Anchorage, Ak 99519 50- ',1-3~-20116-02 4. Location of well at surface Grayling Platform ............ :. 9. Unit or Lease Name 1874' FSL, 1386' FEL, Sec. 29, T9N, R13W, SM ~ ............ ..... ~ Trading Bay Unit At Top PrOducing Interval 856' FSL, 2023' FEL, Sec. 33, T9N, R13W, SM ~ :-:',,~.~ J~-~, Grayling G-12RD2 At Total Depth ~ ". ~-. i 11. Field and Pool 180' FSL, 1301' FEL, Sec33, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. McArthur River Field 103' RKB above MSL ADL 17594 Hemlock and Middle Kenai "G" Zone i2. Date Spudded5/21/1987 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °fish°re6/12/1978 3131/98 125' feet MS L 16. No. of Completions1 , 17. Total Depth (MD+TVD)i 3,800'/10,097' 18. Plug Back Depth (MD+TVD)i 3,678'/10,005' I 19' Directi°nal Survey I20' Depth where SSSV setYes: No: NA feet MD I21' Thickness °f Permafr°stNA 22. Type Electric or Other Logs Run Vertical Seismic Profile 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" 1" wall 0 369' Driven Driven 0 17-3/4" .312" wall 0 602' 22" 775 sx 0 13-3/8" 61# K-55 0 6013' 18" 2525 sx 0 9-5/8" 40-47# N-80/P-110 0 10,257' 12-1/4" Window 0 7" 29# N-80 9734' 13,782' 8-1/2" 700 sx 0 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) See Attachment 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.)t,)l'",~..~]~.- , [ '~ J'-'t L NA for injector Iflowing to flare for test Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO NA NA TEST PERIOD => NAI NA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. NA NA 24-HOUR RATE => NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED OCT O Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~0il&6as~~~ Su~lll~l~lI~cate --Oct, 7, 1998-7'1lAM UNOCAL CORP No,zuz4 F, z !zu, ' ............................ 30. ' OEOLOGIC MARKERS ~' FORMATIr ~$T$ [- iii ........... . ................... iii ii , ~.,~...,. l 1, i, . NAME Include in~al t.sted, pmesum da~, all fluids ~vemd and gravl~, ....... M'~S. DEP~ TRUE ~ DEP~ GOR, and ti~ of ea~ phase. ,, , G!ST 12,241' 8899' H~ 12,962' ~8' ~1. LIST OF A~ACHMENTS Weilbore sc~matl~, Dail~,,.$,~mma~ ~ Rig Opemtlon~, Dl~tlonal 8uwey Reco~ ................. algae ~. _t . Title Drt!~!~_o Manaaaf Date · -., ...................... .... ~ . -- ,.,,t, ) .... ,,.,,,, -, Form ~0..407 INSTRUCTION8 General: Tills fon~ is ¢leslgned for submitting a oomplete and correct well completion repo~ and log on all typee of lance 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 roi' tn-sttu combustion. Item .5: Indicate which elevation Is used as reference (where not otilenviae shown) for depth measurements given In other space on this form an~ in any attachments, Item 16 and 24: If this well le oompleted for separate production from more than one Interval (multiple completion), so state in item 15, and In item 24 show the productin intervals for only, the interval reported In Item 27..~ubmlt 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, eft=.). I[em 2;;3: Attached supplemental m~ordl for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Metllod of Opemtlon: 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", ERFORATION DATA SHEET Grayling G- 12RD2 Perforate G-zone with 4-5/8" TCP Hollow Carrier Guns, 6 HPF, 60 deg phasing Date Zone Interval MD Interval TVD 9/14/98 G-2 12305'-12339' 8948'-8975' 9/14/98 G-3 12362'-12372' 8992'-9000' 9/13/98 G-3 12378'-12388' 9005'-9012' 9/13/98 G-3 12403'-12413' 9023'-9032' 9/13/98 G-4 12480'-12550' 9083'-9134' 9/13/98 G-4 12560'-12575' 9142'-9153' 9/12/98 G-5 12687'-12717' 9237'-9260' 9/12/98 G-5 12732'-12752' 9271 '-9286' Perforations Open to the Wellbore MD TVD 12305'-1 12362'-1 12378'-1 12403'-1 12480'-1 12560'-1 12687'-1 12732'-1 2339' 8948'-8975' 2372' 8992'-9000' 2388' 9005'-9012' 2413' 9023'-9032' 2550' 9083'-9134' 2575' 9142'-9153' 2717' 9237'-9260' 2752' 9271'-9286' 12975'-13008' 13265'-13390' 9458'-9484' 9688'-9787' perfdata. DOC Tim Billingsley 9/22/98 Orig RKB to TBG Head -- 43.2' Tree connection: 9734' 10,257 Bad csg 13,205' to 13,220' Taper mill ran on 5/21/87 showed undersized csg. PL ran on 5/26/87 prior to acid stim. showed 100% of water going out this interval Addedd G-2 thru G-5 perfs -- 12305'- - 12752' B-1 B-4 ETD = 13,678' TD -- 13,800' RT to MLLW ELEV -- 103' MAX ANGLE = 59.300 @ 2500' KO P @ 10,262' Completed Trading Bay Unit Well # G-12RD2 3/31/98, Perfed 9/12-14/98 SIZE WT GRADE CASING AND TUBING DETAIL MD MD TVD CONN ID TOP BTM. BTM. CMT 26" 1/2" Wall Surf. 369' 17-3/4" .312 wall Weld Surf. 602' 13-3/8" 61 K~55 Butt 12.515 Surf. 6013' 9-5/8" 47 P- 110 Seal Lock 8.681 Surf. 73' 9~5/8" 40# N~80 Seal Lock 8.835 73 6252' 9-5/8" 43.5# N~80 Seal Lock 8.755 6251' 6939' DV Collar ....................................................................... 6939' 6941' 9-5/8" 43.5# N-80 Seal Lock 8.755 6941' 9276' 9-5/8" 47 N-80 Seal Lock 8.681 9276.06' Q) 10,257' 7" 29 N~80 Butt 6.184 9734' ! 3,782' Tubing: 3-1/2" 9.3 L-80, EUESrd 2.992 0' 12,154' JEWELRY DETAIL NO. Depth Il) Item 10,575 , Driven 775 sx 2525 sx 800 sx 43.2' 1 12,072' 3.25 2 2 12,119' 2.813 2a 12,151' 2.781 12,154' 2.992 3 12,882' 4.00 4 12,885' 4.00 5 12,894' 6 12,895' 2.75 7 12,925' 2.99 btm 12,926' 3-1/2" C1W Tubing Hanger, 8rd top and butt bottom 3-1/2" 8rd mod x 3-1/2" butt AB mod xover Baker SAB Hyd permanent pkr with anchor X nipple Baker Model "E" Hydro-trip sub w/mule shoe Note: 2.72" blind box was needed to beat thru hydrotrip sub on 9/11/98 Baker 8rd Wireline Muleshoe Baker Model "FB- 1" Pkr Seal Bore Ext. Cross Over Otis "X" Profile Nipple WLEG FISH Milled up packer 5/21/87 STIMULATIONS Acidize B-1 w/24 bbls ofHCL & 75 bbls of mud acid 5/28/87 SLICKLINE WORK Tagged fill wi 2.5" GR 1995 13,679' 13,423' PERFORATION DATA Accum -as~ Zone Top Btm Amt SPF Perf Date Present Condition (~-z 12305 12339 34 6 9114198 Open G-3 12362 12312 lO 6 9114/98 Open G-3 12318 12388 10 6 9/13198 open G-3 12403 12413 10 6 9113198 Open G-4 1248U 12550 lO 6 9/13/98 Open ~-4 12560 12515 15 6 9113198 Open G-5 12681 12117 30 6 9112198 open G-5 12132 12152 20 6 9/12198 Open 12,972' 12,974' 4' 4 6/20/78 Sqz Perfs I~-1 12,975' 13,005' 30' 12 5/25/87 open t/Injection u-q 12,978' 13,008' 30' 4 1/28/98 L)pen t/Injection 13,014' 13,016' 2' 4 6/19/78 Sqz Perfs B-4 13,265' 13,390' 125' 12 5/25/~ / Open t/Injection 13,410' 13,412' 2' 4 6/19/78 5qz F'erts G12RD2schem91498.doc DRAWN BY: TAB REVISED: 09/17/98 UNOCAL ) Grayling G-,2RD2 Workover Daily Summary 3/26198 to 3131/98, 914/98 to 9/14198 G-12RD2 Workover Daily Summary 3/26/98 Test tubing x 9-5/8" annulus to 2250 psi for 30 min. Set BPV, ND tree. NU and test BOPE. Pulled tbg seals from packer. Displace well with 3% KCL/FIW. 3/27/98 POOH laying down 3-1/2" tubing. RIH with 7"x 9-5/8" tandem casing scrapers to 12,795'. Circ BU. 3/28/98 POOH with scrapers. RU Schlumberger and ran Vertical Seismic Profile log. 3/29/98 Finish VSP log. Run packer and 3-1/2" 8rd mod inj tubing. 3/30/98 Displace annulus to corrosion inhibited 3% KCL. POOH with packer and tubing to replace shear out sub with Hydro-trip sub. Rerun packer and tubing. 3/31/98 Drop ball and set packer at 12072' MD/8765' TVD. Pressure test annulus to 2250 psi for 30 min with no bleed-off. Land hanger, ND BOPE, NU and test tree. Release rig from G-12RD2. Perform MIT pressure test on tubing x 9-5/8" casing annulus. Pressure test to 2250 psi with no bleed-off in 30 min. Resume injection into existing Hemlock Bench 1 and Bench 4 perforations. 9/4/98 RU slickline. RIH with 2.7" gauge ring and set down at hydro-trip sub at 12,186' wlm. RIH with 2.6" GR and set down at 12,186'. RIH with 2.5" GR and set down at 12,186'. RD slickline. 9/10/98 RU slickline. RIH with 2.75" impression block. Set down at 12,151'wlm. POOH with lB, marks around edge and one smooth mark in middle. RIH with 2.73" swedge, could not work past 12,151'. POOH with swedge. RIH with 2.25" blind box. Set down at 12,151' and beat down once to fall through. Work up and down through bad spot several times with no further problems. POOH with 2.25" blind box. 9/11/98 9/12/98 RIH with 2.5" blind box to 12,151'. Beat down twice and fell through. PU through 12,151' with no indication of tight spot. RIH slow and see~tight spot. POOH with 2.5" blind box. RIH with 2.72" blind box to 12,151'. Beat down twice and fall through. RIH and tag at 12,870'. POOH with 2.72" blind box. RU E-line unit. Run TDT log from 12,850' to 12,000'. RU to add G-zone perforations. RIH with gun #1 and perforate 12,732'-12,752' with 2.5" hollow carrier 6 spf 60 degree phasing. RIH with Gun #2 and perforate 12,687'-12,717'. 9/13/98 RIH with Gun #3 and perforate 12,560'-12,575'. RIH with Gun #4 and perforate 12,520'-12,550' RIH with Gun #5 and perforate 12,500'-12,520'. b g12daily summary.doc 1 9/18/98 UNOCAL ) Grayling G-,)RD2 Workover Daily Summary 3/26/98 to 3/31/98, 9/4/98 to 9114198 RIH with Gun #6 and perforate 12,480'-12,500'. RIH with Gun #7 and perforate 12,403'-12,413'. RIH with Gun #8 and perforate 12,378'-12,388'. 9/14/98 RIH with Gun #9 and perforate 12,362'-12,372'. RIH with Gun #10 and perforate 12,319'-12,339'. RIH with Gun #11 and misfire. RIH with Gun #12 and perforate 12,305'-12,319'. b g12daily summary.doc 2 9/18/98 STATE OF ALASKA ALASKA OIL/- 3 GAS CONSERVATION CON :SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: SERVICE: X Water Injector 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 78-042 3. Address 8. ~j~. umber P. O. Box lg6247, Anchorage, Ak g9519 50- ,1-B45'-20116-02 4. Location of well at surface Grayling Platform ~.~, ...... ~;~...,~:.~,7.% g. Unit or Lea~e Name r 1874' FSL, 1386' FEL, Sec. 29, T9N, R13W, SM j ~~ ii Trading Bay Unit At Top Producing Interval k~--,.r .'~J~ II 10. Well Number 856' FSL, 2023' FEL, Sec. 33, T9N, R13W, SM ~ih""~iL':~.~¢__~....i Grayling G-12RD2 At Total Depth ................. ~;, 1 i. Field and Pool 180' FSL, 1301' FEL, Sec33, T9N, R13W, SM 5.'Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. McArthur River Field 103' RKB above MSLI ADL 17594 Hemlock and Middle Kenai "G" Zone 12. Date Spudded5/21/1987 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °fish°re I 16' N°' °f C°mpleti°ns6/12/1978 3/31/98 125' feet MSL 1 17. Total Depth (MD+TVD)18. Plug Back Depth (MD+TVD)13,800,/10,097, 13,678'/10,005' 19' Directi°nal Survey I 20' Depth where SSSV set Yes: No: NA feet MD i21' Thickness °f Permafr°st NA 22. Type Electric or Other Logs Run Vertical Seismic Profile 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" 1" wall 0 369' Driven Ddven 0 17-3/4" .312" wall 0 602' 22" 775 sx 0 13-3/8" 61# K-55 0 6013' 18" 2525 sx 0 9-5/8" 40-47# N-80/P-110 0 10,257' 12-1/4" Window 0 7" 29# N-80 9734' 13,782' 8-1/2" 700 sx 0 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) See Attachment 26. ACID, FRACTURE, CEMENT SQUEEZE,'ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ............. 27. PRODUCTION TEST DUPL Date First Production I Method of Operation (Flowing, gas lift, etc.) I U NA for injector Iff. owing to flare for test Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE I GAS-OIL RATIO · I NA NA TEST PERIOD => NA NA FI~v Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER~BBL OIL GRA~I'TY-API (corr) Press. NA NA 24-HOUR RATE => NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chip~. None Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE it in duplicate GEOLOGIC MARKERS I F:ORM^T, 'EST$ I NAME Include interval tested, preesure data, all fluids recave~l and gravity, ME.~.$. DEPTH TP. UF_. VEP. T. DEP'r'~t GOR, and time of ear.,h phase. G 1 ST 12,241' ~$99' HK'I' ~ 2,962' ~,-48' ;31. LIST OF ATTACHMENTS Wellbore scl~ematlo, Dall,y .8..ummary of Rig Operations. Directional Survey Reco~ .......... 32. I hereby certify that the foregol?~ ~/ft~ue and co.ct to the best of my knowledg'~ ........ $1gne }L- -' t~ . Trtle Drllltno Maneaer Date Form 10-407 INSTRUCTIONS Generat: Thi~ form is desfgn~ for submitting a complete and cae'eot well completion report and log on atl ~/ges of lande arid tee, sas in Alaska. item 1: Classification of Service Wells: Gas injection, water' Injection, steam injection, air injection, salt water disposal, water supply for injection, el~servatlon, [~lectlon for In-situ ¢omD~letion. Item §: Indicate which elevation Is uaed as reference (where not oMlerwisa shown) ~or depth measurements given In other space on this form anct in any attacllmems, Item 16 and 24: If this well I, cornplet.d for ~eparate procluctton from more than one Interval (multiple completion), so state in item 18, and In Item 24 show the pro~uctin intervals for only th. interval repo~ted In Item ?_7..~ubmlt a separate form for sash additional Interval to be separately produced, showing the data pertinent to such Inter'vel. Item 21: Indicate whether f~om ground level (GL) or other elevation (DF, KB, eta.). Item 23: Attached supl~lamen~al re~a~ls f~r this well should show the detalia of any rnultlgle stage cement- ing and the location of the cementing tool. Item 27': Method of Operation: Flowing, Ga~ Lift, Rod Pump, l-tydraullc Pump, Submersible, Water In- jection, Gee Injection, Shut-In, Other.explain. Item 28: If no cores taken. Indtmtto "none~, ~-'--_RFORATION DATA SHEET Grayling G-12RD2 Perforate G-zone with 4-5/8" TCP Hollow Carrier Guns, 6 HPF, 60 deg phasing Date Zone Interval MD Interval TVD 9/14/98 G-2 12305'-12339' 8948'-8975' 9/14/98 G-3 12362'- 12372' 8992'-9000' 9/13/98 G-3 12378'- 12388' 9005'-9012' 9/13/98 G-3 12403'- 12413' 9023'-9032' 9/13/98 G-4 12480'- 12550' 9083'-9134' 9/13/98 G-4 12560'-12575' 9142'-9153' 9/12/98 G-5 12687'- 12717' 9237'-9260' 9/12/98 G-5 12732'- 12752' 9271 '-9286' Perforations Open to the Wellbore MD TVD 12305'-12339' 8948'-8975' 12362'-12372' 8992'-9000' 12378'-12388' 9005'-9012' 12403'-12413' 9023'-9032' 12480'-12550' 9083'-9134' 12560'-12575' 9142'-9153' 12687'-12717' 9237'-9260' 12732'-12752' 9271'-9286' 12975'-13008' 9458'-9484' 13265'-13390' 9688'-9787' perfdata.DOC Tim Billingsley 9/22/98 Orig RKB to TBG Head = 43.2' Tree connection: 9734' 10,257 Bad csg 13,205' to 13,220' Taper mill ran on 5/21/87 showed undersized cs#. PL ran on 5/26/87 prior to acid slim. showed 100% of water going out this iniervai Addedd G-2 thru G-5 perfs = 12305'- 12752' 12,882'..-~ ~ ~4 3 B-1 13-4 ETD = 13,678' TD -- 13,800' RT to MLLW ELEV = 103' MAX ANGLE = 59.300 @ 2500' KOP @ 10,262' Completed Trading Bay Unit Well # G-12RD2 3/31/98, cerfed 9/12-14/98 SIZE WT GRADE CASING AND TUBING DETAIL MD MD TVD CONN ID TOP BTM. BTM. 26" 1/2" Wall 17-3/4" .312 wall 13-3/8" 61 K-55 9-5/8" 47 P-110 9-5/8" 40# N-80 9-5/8" 43.5# N-80 DV Collar ........ 9-5/8" 43.5# N-80 9-5/8" 47 N-80 7" 29 N-80 Tubing: 3-1/2" 9.3 L-80, Surf. 369' Weld Surf. 602' Butt 12.515 Surf. 6013' Seal Lock 8.681 Surf. 73' Seal Lock 8.835 73 6252' Seal Lock 8.755 6251' 6939' 6939' 694l' Seal Lock 8.755 6941' 9276' Seal Lock 8.681 9276.06' (D 10,257' Butt 6.184 9734' 13,782' EUESrd 2.992 0' 12,154' 10,575 , NO. Depth JEWELRY DETAIL ID Item 43.2' 1 12,072' 2 2 12,119' 28 12,151' 12,154' 3 12,882' 4 12,885' 5 12,894' 6 12,895' 7 12,925' btm 12,926' 3-1/2" CFC/Tubing Hanger, 8rd top and butt bottom 3-1/2" 8rd mod x 3-1/2" butt AB mod xover 3,25 Baker SAB Hyd permanent pkr with anchor 2.813 X nipple 2.781 Baker Model "E" Hydro-trip sub w/mule shoe Note: 2.72" blind box was needed to beat thru hydrotrip sub on 9/11/98 2.992 Baker 8rd Wireline Muleshoe 4, 00 Baker Model "FB- 1" Pkr 4,00 Seal Bore Ext. Cross Over 2,75 Otis "X" Profile Nipple 2.99 WLEG FISH Milled up packer 5/21/87 STIMULATIONS Acidize B-1 w/24 bbls ofHCL & 75 bbls of mud acid 5/28/87 ~ 13,679' SLICKLINE WORK Tagged fill w/2.5" GR 1995 ~ 13,423' PERFORATION DATA " ,,, Accum LaSt Zone Top Btm Amt SPF Perf Date Present Condition ~-2 12305 12339' 34' 5 9114/'98 Open G-3 "12362 12372 10 § 9114/98 Open , .. (~-3 12318 12388 10 6 9113198 open G-3 I' 12403 12413 10 § 9113/98 Open , ~-4 12480 12550 70 6 9113198 Open [5-4 12560 12575 .15 6 9/13198 open 5-5 12581 12111 30 § 911~98 Open ~-5 12732 12752 20 6 9112J98 ope'n 12,972' 12,974' 4' 4 6/20/78 Sqz Perfs ~-1 12,975' 13,005' 30' 12. .... 5/25/87 open t/~njectib'n ' ~-1 12,978' 13,008' 30" 4 1/28/98 Open ti Injection 13,014' 13,016' 2' 4 6/19/78 Sqz Perfs ~4 13,265' 13,390' '12b' 12 ~1'25/~ [ Open t/Injection ,,, 13,410' 13,412' 7' ' 4 6/19/78 5qz Per-rs CMT Drivell 775 sx 2525 sx 800 sx G12RD2schem91498.doc DRAWN BY: TAB REVISED: 09/17/98 UNOCAL ) Grayling G- ~,D2 Workover Daily Summary 3/26/98 to 3/31/98, 9/4/98 to 9/14/98 G-12RD2 Workover Daily Summary 3/26/98 Test tubing x 9-5/8" annulus to 2250 psi for 30 min. Set BPV, ND tree. NU and test BOPE. Pulled tbg seals from packer. Displace well with 3% KCL/FIW. 3/27/98 POOH laying down 3-1/2" tubing. RIH with 7"x 9-5/8" tandem casing scrapers to 12,795'. Circ BU. 3/28/98 POOH with scrapers. RU Schlumberger and ran Vertical Seismic Profile log. 3/29/98 Finish VSP log. Run packer and 3-1/2" 8rd mod inj tubing. 3/30/98 Displace annulus to corrosion inhibited 3% KCL. POOH with packer and tubing to replace shear out sub with Hydro-trip sub. Rerun packer and tubing. 3/31/98 Drop ball and set packer at 12072' MD/8765' TVD. Pressure test annulus to 2250 psi for 30 min with no bleed-off. Land hanger, ND BOPE, NU and test tree. Release rig from G-12RD2. Perform MIT pressure test on tubing x 9-5/8" casing annulus. Pressure test to 2250 psi with no bleed-off in 30 min. Resume injection into existing Hemlock Bench 1 and Bench 4 perorations. 9/4/98 RU slickline. RIH with 2.7" gauge ring and set down at hydro-trip sub at 12,186' wlm. RIH with 2.6" GR and set down at 12,186'. RIH with 2.5" GR and set down at 12,186'. RD slickline. 9/10/98 RU slickline. RIH with 2.75" impression block. Set down at 12,151'wlm. POOH with lB, marks around edge and one smooth mark in middle. RIH with 2.73" swedge, could not work past 12,151'. POOH with swedge. RIH with 2.25" blind box. Set down at 12,151' and beat down once to fall through. Work up and down through bad spot several times with no further problems. POOH with 2.25" blind box. 9/11/98 9/12/98 RIH with 2.5" blind box to 12,151'. Beat down twice and fell through. PU through 12,151' with no indication of tight spot. RIH slow and see'tight spot. POOH with 2.5" blind box. RIH with 2.72" blind box to 12,151'. Beat down twice and fall through. RIH and tag at 12,870'. POOH with 2.72" blind box. RU E-line unit. Run ,TDT log from 12,850' to 12,000'. RU to add G-zone perorations. RIH with gun #1 and perorate 12,732'-12,752' with 2.5" hollow carrier 6 spf 60 degree phasing. RIH with Gun #2 and perorate 12,687'-12,717'. 9/13/98 RIH with Gun #3 and perorate 12,560'-12,575'. RIH with Gun CfA and perorate 12,520'-12,550' RIH with Gun #5 and perforate 12,500'-12,520'. b g12daily summary.doc 1 9/18/98 UNOCAL Graylin(.. .12RD2 Workover Daily Summary 3/26/98 to 3/31/98, 9/4/98 to 9/14/98 i i iiii ii i iii i iiiiii ii i RIH with Gun #6 and perforate 12,480'-12,500'. RIH with Gun #7 and perforate 12,403'-12,413'. RIH with Gun #8 and perforate 12,378'-12,388'. 9/14/98 RIH with Gun #9 and perforate 12,362'-12,372'. RIH with Gun #10 and perforate 12,319'-12,339'. RIH with Gun #11 and misfire. RIH with Gun #12 and perforate 12,305'-12,319'. b g 12daily summary.doc 2 9/18/98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: 103' KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface Grayling Platform Leg # 2, Conductor # 37 8. Well number 1,874' FSL, 1,386' FEL, Sec. 29, T9N, R13W, SM G-12rd2 At top of productive interval 12,962' MD 9. Permit number 565' FSL, 1,736' FEL, Sec. 33, T9N, R13W, SM 78-042 At effective depth 13,679' MD 10. APl number 235' FSL, 1,364' FEL, Sec. 33, T9N, R13W, SM 50-133-20116-02 At total depth 13,800' MD 11. Field/Pool 180' FSL, 1,301' FEL, Sec. 33, T9N, R13W, SM McArthur River / "G" & Hemlock 12. Present well condition summary~L~ ~.-~r'" ~. i.~ [~l ~t~/~ i~ ~- Total depth: measured 13,800' feet Plugs (measured) true vertical 10,110' feet Effective depth: measured 13,679' feet Junk (measured) 13,679' true vertical 10,005' feet AlaSk~ 0~.'.,~ '~ ;'.~2~: ~' ~',~.~ ~ ~ ,.~.," ~.;0~'n~;~sS~0[~ casing Length Size Cemented Measured depth True vert ca depth Structural 369' 26" Driven 369' 369' Conductor 602' 17-3/4" 775 sx 602' 602' Surface 6,013' 13-3/8" 2,525 sx 6,013' 4,237' Intermediate Production 10,257' 9-5/8" Window 10,257' 7,439' Liner 4,036' 7" 700 sx 9,746'- 13,782' 10,095' Perforation depth: measured 12975'- 13008', 13265'- 13390' true vertical 9488'-9512'; 9700'-9800' Tubing (size, grade, and measured depth) 3-1/2", 9.2~, N-80 ~ 12,925' Packers and SSSV (type and measured depth) Baker FB-1Pkr. ~ 12,885'.ORIGINAL 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 2/23/1998 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injector 17. I hereby certi~ that the foregoing is true and correct to the best of my knowledge. Signed: ~ ),~, ~M ~' ,~- Dale A. Haines Title: Drilling Manager Date: ~"{ ¢i ~'~ FOR COMMISSION USE ONLY Conditions of approval: Noti~ Commission so representative may witness l Approval N~ Plug integri~.~ BOP Test ~ Location clearance I 0 Mechanical Integrity Test ~ Subsequent form required 10- ~ ~ ~ Aoproved C~PY ' Returng~ ~ Original Signed By David W. Johnston Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCAL Grayling Wel, .,.12RD2 Rig Workover AFE #130341 Workover Procedure Objective: The objective of the workover on G-12RD2 is to gain access to the G-zone. The well is currently a water injector in the Hemlock. The proposed workover will remove the tubing from the existing packer above the Hemlock. A new packer will be run above the G- zone. After the rig workover, G-zone perforations will be added with through-tubing guns and injection will resume into the G-zone and Hemlock. G-12RD2 passed an MIT on 10/3/97. Workover Procedure: 1. Check tubing for pressure. Ensure annulus is full of liquid. 2. Install back pressure valve. ND tree. 3. NU BOPE, pull BPV and install 2-way check. witness. Test BOPE with 24 hr notice given to AOGCC for 4. Pull 2-way check valve. Engage tubing hanger with landing joint. Kill well with FIW if necessary. 5. Pull tubing 10' and monitor well, circulate FIW down tubing and up annulus (1-1/2 well volumes) to ensure well is clear of gas. 6. POOH laying down tubing. 7. Run completion with hydraulic set permanent injection packer and 3-1/2" tubing. 8. Land hanger, drop ball to set packer at 12,140' MD/8833' TVD. Pressure test annulus to 2250 psi. 9. Pressure up to blow out ball. 10. Set BPV and ND BOPE. NU tree and retest annulus to 2250 psi with AOGCC witness for injection well MIT. 11. Release rig. Start water injection. 12. RU Schlumberger and perforate the following intervals: G-2 12306'-12340' G-3 12364'-12374' 12382'-12392' 12410'-12415' G-4 12480'-12550' 12560'-12575' G-5 12690'-12720' 12735'-12755' 12RD2 Procedure 2-9-98.DOC 2/10/98 UNOCAL ) RKB to TBG Head = 42.6' Tree connection: 9734' Trading Bay Unit Well # G-12RD2 Completed 5/30/87 CASING AND TUBING DETAIL MD MD TVD SIZE WT GRADE CONN ID TOP BTM. BTM. 26" 1/2" Wall Surf. 369' 17-3/4" .312 wall Weld Surf. 602' 13-3/8" 61 K-55 Butt 12.515 Surf. 6013' 9-5/8" 47 P-110 Seal Lock 8.681 Surf. 73' 9-5/8" 40# N-80 Seal Lock 8.835 73 6252' 9-5/8" 43.5# N-80 Seal Lock 8.755 6251' 6939' DV Collar 6939' 6941' 9-5/8" 43.5// N-80 Seal Lock 8.755 6941' 9276' 9-5/8" 47 N-80 Seal Lock 8.681 9276.06' (i) 10,257' 7" 29 N-80 Butt 6.184 9734' 13,782' Tubing: 3-1/2" 9.3 N-80, IPC Seal Lock 2.992 0' 12,925' 10,575 , CMT Driven 775 sx 2525 SX 800 sx 10,257 JEWELRY DETAIL N.o. Depth ID Item 42.6' 3-1/2" CIW Tubing Hanger 1 12,847' 2.75 Otis "XA" Sliding Sleeve 2 12,881' Baker Locator Seal Assy. w/' of seals. 3 12,882' 4.00 Baker Model "FB- 1" Pkr 4 12,885' 4.00 Seal Bore Ext. 5 12,894' Cross Over 6 12,895' 2.75 Otis "X" Profile Nipple 7 12,925' 2.99 WLEG btm 12,926' 12,882' 3 FISH Milled up packer 5/21/87 STIMULATIONS Acidize B-1 w/24 bbls ofHCL & 75 bbls of mud acid 5/28/87 (.~ 13,679' SLICKLINE WORK Tagged fill w/2.5" GR 1995 ~(~ 13,423' B-1 Bad csg 13,205' to 13.220' Taper milt ran on 5/21/87 showed undersized cag. PL ran on 5/26/87 prior to acid stim, showed 100% of water going out this interval B-4 ETD = 13,678' TD = 13,800' RT to MLLW ELEV = 99' MAX ANGLE = 59.300 @ 2500' KO P @ 10,262' G-12RD2.DOC PERFORATION DATA , i Accum LaSt Zone , Top Btm Amt SPF Perf Date Present Condition ! 12,972' '" 12,974' 4' 4 6/20/78 Sqz Perfs I~-1 ' [ '12,975' '"' 13,005' 30' 12 5/25/87 Opbn ti'Injection "[ '12,978' 13008' 30' 4 1/28/98 ~<epert i3,014' 13,016' 2' 4 6/19/78 Sqz PeFfs B4 . 13,265' 13,390' '125' ' 12 ' 5/Z~/~[ L)pen t/Injection "/ 13,410' 13,412' ' 2' ""4 6/19/78 5qz Perts , '' REVISED: 8/12/97 DRAWN BY: SLT RKB to TBG Head = 42.6' Tree connection: 9734' 10,257 12,882' Proposed G-2thru G-5 perm 12306'- 12755' Bad csg 13,205' to 13,220' Taper mill ran on 5/21/87 showed undersized csg. PL ran on 5/26/87 prior to acid stim. showed 100% of water going out this interval B-1 B-4 Trading Bay Unit Well # G-12RD2 Proposed 3/98 CASING AND TUBING DETAIL MD MD TVD SIZE WT GRADE CONN 1D TOP BTM. BTM. 26" 1/2" Wall Surfi 369' 17-3/4" .312 wall Weld Surf. 602' 13-3/8" 61 K-55 Butt 12.515 Surt: 6013' 9-5/8" 47 P-110 Seal Lock 8.681 Surf. 73' 9-5/8" 40# N-80 Seal Lock 8.835 73 6252' 9-5/8" 43.5# N-80 Seal Lock 8.755 6251' 6939' DV Collar ....................................................................... 6939' 6941' 9-5/8" 43.5# N-80 Seal Lock 8.755 6941' 9276' 9-5/8" 47 N-80 Seal Lock 8.681 9276.06' (i) 10,257' 7" 29 N-80 Butt 6.184 9734' 13,782' Tubing: 3-1/2" 9.3 L-80, EUE8rd 2.992 0' 12,200' 10,575 , JEWELRY DETAIL NO. Depth ID Item 42.6' 3-1/2" CIW Tubing Hanger 1 12,140' Hyd pem~anent pkr with anchor 2 2 12,170' 2.75 X nipple 2a 12,200' 2.99 WLEG tubing tail 3 12,882' 4.00 Baker Model "FB-I" Pkr 4 12,885' 4.00 Seal Bore Ext. 5 12,894' Cross Over 6 12,895' 2.75 Otis "X" Profile Nipple 7 12,925' 2.99 WLEG btm 12,926' FISH Milled up packer 5/21/87 STIMULATIONS Acidize B-1 w/24 bbls ofHCL & 75 bbls of mud acid 5/28/87 SLICKLINE WORK Tagged fill w/2.5" GR 1995 (,~ 13,679' 13,423' PERFORATION DATA Accum Las[ Zone Top Btm Amt SPF Perf Date Present Condition G-2 123o6 12340 34 Proposed G-3 12364 12374 10 Proposed G-3 12382 12392 10 Proposed (5-3 12410 12415 5 Proposed G-4 12480 12550 70 Proposed -- G-4 12560 12575 15 Proposed G-5 12690 12720 30 Proposed C~-5 12735 12755 20 Proposed 12,972' 12,974' 4' 4 6/20/78 Sqz Peris Id-1 12,975' 13,005' 30' 12 5/25/87 Open t/Injection B-1 12,975' 13,005' 30' Proposed Betore wort(over 13,014' 13,016' 2' 4 6/19/78 Sqz Peris t3-4 13,265' 13,390' 125' 12 5/25/87 Open t/Injection 13,410' 13,412' 2' 4 6/19/78 5qz I~erts CMT Driven 775 sx 2525 sx 800 sx ETD = 13,678' TD = 13,800' RT to MLLW ELEV = 99' MAX ANGLE = 59.30° @ 2500' KO P @ 10,262' G12RD2prop.DOC REVISED: 01/16/98 DRAWN BY: TAB MIXINO PIT 4o Bi3LS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM , /..// TRIP TANK BBLS 185 BBLS VOLUME PIT 185 BBLS SUCTION PIT 125 BBLS DEGASSER 67 BBLS ! DESILTER i 2~0 BBLS SHAKER SHAKER i CF'I,¢I'"~ IFU CE RESERVE PIT 475 BBLS NOTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL INDICATOR WITH AUDIO &: VISUAL WARNING DEVICES. EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 2) (2) SHAKERS 4) PIT LEVEL INDICATOR (VISLIAL & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS 8) DESILTER 9) CENTRIFUGE 10) MIXING PIT UNOCAL GRAYLING MUD PIT SCHEMATIC DRAWN 13Y: DAC APP'D: GSEI SCALE: NONE DATE: 3" KILL LINE WITH TWO 3" 5U VALVES [ .... q'; ,'_r; KILL LINE FROM MUG PMP &: CEMENT UNIT NIPPLE I FLOWLINE ,, ~-~/a" ~ooo Psl ANNULAR L [...__.~. ~ T P~PE RAMS PIPE RAMS 1 15-5/8" ,.fi,k{ FLANGE DOUBLE GATE 5M BLIND RAMS 15-5/8" 5M FLANGE ] 4." CHOKE LINE WITH ONE REMOTE ..... ~ 1 MANUAL 4." 5M VALVE ,'l; (!; ~ CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) RISER 15-5/8" 5M FLANGE SINGLE GATE 5M ~5-5/a" 5M FLANOE 10" 5M x 15-5/8" ADAPTER CAMERON 5M SPOOL ~;-5/a" soPz 5~ S~'ACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) '-~RAWN: DAC APP'D' SCALE: NONE DATE: 6/24/91 TO DERRICK VENT TO GAS BUSTER /\ AUTOMATIC I~ -'~x..~~~ ~ AUTO/WATIC CHOKE CHOKE l'O WELL. CLEAN TANK FRONi CHOKE LINE VALVES UPSTREANI OF CHOKES ARE lO,Q00 PSI GATE TYPE VALVES 00WNSTREAk~ OF CHOKES ARE 5,000 PSI GATE TYPE UNION CHOKE NtANIFOLD · . GRAYLING PLATFORM OIL COktPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'O' SCALE: NONE 0ATE: 11/2o/a9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: KB: 103' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: X Trading Bay Unit 4. Location of well at surface Grayling Platform Leg # 2, Conductor # 37 8. Well number 1,874' FSL, 1,386' FEL, Sec. 29, TgN, R13W, SM G-12RD2 At top of productive interval 12,962' MD 9. Permit number/approval number 565' FSL, 1,736' FEL, Sec. 33, T9N, R13W, SM 78-042 At effective depth 13,679' MD 10. APl number 235' FSL, 1,364' FEL, Sec. 33, T9N, R13W, SM 50- 133-20116-02 At total depth 13,800' M D 11. Field/Pool 180' FSL, 1,301' FEL, Sec. 33, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 13,800' feet Plugs (measured) true vertical 10,110' feet Effective depth: measured 13,679' feet Junk (measured) 13,679' true vertical 10,005' feet Casing Length Size Cemented Measured depth True vertical depth Structural 369' 26" Driven 369' 369' Conductor 602' 17-3/4" 775 sx 602' 602' Surface 6,013' 13-3/8" 2,525 sx 6,013' 4,237' Intermediate Production 10,257' 9-5/8" Window 10,257' 7,439' Liner 4,036' 7" 700 sx 9,746'- 13,782' 10,095' Perforation depth: measured 12975'- 13008', 13265'- 13390' Perforated 1/28/98, Please see attachments for details. true vertical 9488'-9512'; 9700'-9800' '~,~ . Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 12,925' ': '~'~ ~ii~' ;~ ?" ~: Packers and SSSV (type and measured depth) Baker FB-1 Pkr. @ 12,885'. '"' 13. Stimulation or cement squeeze summary ~-'"':,.' Intervals treated (measured)ORIGINAL Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1/25/1998 0 0 2185 2300 2750 Subsequent to operation 2/8/1998 0 0 2776 1000 3200 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: Suspended: Service: X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dale A. Haines /,~.~ ~t Cc:'-.- Title: Drilling Manager Date: Feb. 10, 1998 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCAL RKB to TBG Head = 42.6' Tree connection: 9734' Trading Bay Unit Well it G-12RD2 Completed 5/30/87 CASING AND TUBING DETAIL MD MD TVD SIZE WT GRADE CONN ID TOP BTM. BTM. 26" I/2" Wall Surf. 369' 17-3/4" .312 wall Weld Surf. 602' 13-3/8" 61 K-55 Butt 12.515 Surf. 6013' 9-5/8" 47 P-110 Seal Lock 8.681 Surf. 73' 9-5/8" 40~ N-80 Seal Lock 8.835 73 6252' 9-5/8" 43.5# N-80 Seal Lock 8.755 6251' 6939' DV Collar 6939' 6941' 9-5/8" 43.5# N-80 Seal Lock 8.755 6941' 9276' 9-5/8" 47 N-80 Seal Lock 8.681 9276.06' (D 10,257' 7" 29 N-80 Butt 6.184 9734' 13,782' Tubing: 3-I/2" 9.3 N-80, IPC Seal Lock 2.992 0' 12,925' 10,575 , CMT Driv~ll 775 sx 2525 sx 800 sx 10,257 JEWELRY DETAIL NO. ~?pth ~.~ Item . 42.6' 3-1/2" CIW Tubing Hanger I 12,847' 2.75 Otis "XA' Sliding Sleeve 2 12,881' Baker Locator Seal Assy. w/' of seals. 3 12,882' 4.00 Baker Model "FB-I" Pla' 4 12,885' 4.00 Seal Bore Ext. 5 12,894' Cross Over 6 12,895' 2.75 Otis "X" Profile Nipple 7 12,925' 2.99 WLEG btm 12,926' 12,882' 3 FISH Milled up packer 5/21/87 ~ 13,679' STIMULATIONS A¢idize B-I w/24 bbls ofHCL & 75 bbls of mud acid 5/28/87 SLICKLh-NE WORK Tagged fill wi 2.5" GR 1995 (~ 13,423' B-1 Bad csg 13,205' to 13.220' Taper mill tan on 5/21187 showed undetalzed csg. PL ran on 5/28187 odor to acid stim. showed 100% of water going out this intemal B-4 ETD = 13,678' TD = 13,800' RT to MLLW ELEV = 99' MAX ANGLE = 59.300 @ 2500' KOP @ 10,262' G-12RD2.DOC PERFORATION DATA Accum j casl Zone Top Btm Amt SPF Perf Date Present Condition , ., 12,972' 12,974' 4' 4 i 6/20/78 Sqz Perfs u-1 12.975' 13,005' 30' 12[ 5/25/87 (Jpen ~/injection 13,014' 13,016' 2' 4 6/19/78 Sqz Perfs u4 13,265' 13,390' 125' 1z ~/zb/~ [ upen t/injection 13,41 O' 13,412' z' 4 6/19/78 ~qz ~ens REVISED: 8/12/97 DRAWN By: SLT PERFORATION DATA SHEET GRAYLING G-12RD2 Perforate Hemlock W/2-1/8" Ultra Jet Hollow Carrier Guns, 4HPF, 90 Phase. Date Zone Interval MD Interval TVD 1/28/98 HB-1 12,978' - 13,008' 9,488'- 9,510' ~Q i, ,,ionducicr Flew. 105 li.57 D,.m,~ 43.2 Ft. .590 502.0' /7 `59.0 60!.5.0 13 .5,/8' OD 6i.OOil/il J-55 INT CSG 601.5.0 - 601`5.0' SNOEzd P-!10 $0257.0 - 10257.0' SlOE 97~4 0 1~7°~ ''= , ,. u oz,w /' OD 29.00#/fl N 80 LINER 12972.0 - 12974,0' SQUEEZE PERFS 5/5/78 15011.0 - 15016.0' SQUEEZE PERFS 5/5/78 15165.0 i.5216.0' HOLE 5./26/87 Spli~ or Damaged Csg. I3410,0 - 1.54!2.0' SQUEEZE PERFS 5/5/78 1.5,%, ,=,..0 -- ,, ~.~a,?~ n' FILL i/28/98 E-Line Tag i423.0 - !.5679,0' FiLL 6/9/95 1ag W/2,226' GR 13679.0 15690.0 FILL Tagged While Running Tubing 5/28/87 15690,0 I`5782.0' CEMENT PLUG 13782.0 .- 15782.01 SHOE KB EI.EV: 99' ::~B] D: 15679' TD: ~3800' L 45.2 45.9' HANGER CIW 11" S!ainiess 12894.4 12881.7 12845.5 !2880.8 12975.0 12978.0 12885.0 12895.0 12925.5 15265.0 - 12895.0' ~ 12894,4' 12850,5' - 12881.7' - 15005.0' - 13008.0' 12894.4' - 12896,5' - 12926.4' - 15590.0' CROSSOVER P$SKER Baker FB-/~ 7" Pkr W,/Seal Assy SiErVE O{is LOCATOR JOINT Baker No-Go PERFS HR-l, 8HPF, 7/~/78 & t/27/81 PERFS HB-1, 1/28/98, 4HPF, SBA Baker 2.813"8 iSNDING NIPPLE Oiis 5.75" OD REENTRY JOINT WL Reentry Guide PERFS HB-4, 8HPF, 6/28/78 & 1/27/81 Injection Well pon:~ ho. 2 (.?ample(ed '/ Last Perfd 1/"28ZX98 Oil & Gas Oivi:s,on Unocnl C,;~arst~on Te~eenane ~ -~Q ,"3 Ata~,xa Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. A/~ckorage, A~ 99504 At=n: Ms. Elaine Johnson Dear Ms. Johnson: I have attacked surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Regional Drilling Manager GSB/lew GRAYLING DISTANCE & DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR LEG #3: LAT = 60050' 22.569" LONG =151 °36' 46.519" "Y" COORD. "X" COORD. WELL # 2,502,352.30 212,272.70 FSL 1804 FEL 1409 1 2,502,346.65 212,269.32 G-22 1789 1413 2 2,502,350.14 212,266.48 G-21 1802 1415 3 2,502,354.64 212,266.55 G-26 1806 1415 4 2,502,358.05 212,269.49 G-25 1810 1412 5 2,502,358.77 212,273.94' G-24 1810 1408 6 2,502,356.46 212,277.80 G-20 1808 1404 7 2,502,352.20 212,279.28 18D4 1402 8 2,502,347.99 212,277.68 G-36 1BO0 1'404 9 2,502,345.80 212,273.75 G-34 & RD 1798 1408 10 2,502,350.83 212,270.89 G-23 & RD 1803 1411 ll 2,502,354.60 212,272.33 G-33 1806 1409 12 2,502,351.47~ 212,274.88 G-27 & 28 1803 1407 LEG #4: LAT = 60050' 22.832" LONG =151°36' 48. 042" 1831 2,502,380.80 212,197.90 1486 1 3 2,502,374.34 212,196.66 G-14A 1825 1487 14 2,502,376.65 212,192.79 G-19 1827 1491 15 2,502,380.90 212,191.32 G-13 1831 1493 16 2,502,385.11 212,192.92 G-15 1835 1491 17 2,502,387.30 21 2,196.85 G- 5 1838 1 487 18 2,502,386.45 212,201.28 1837 1483 19 2,502,382.96 212,204.12 G-3 1833 1480 20 2,502,378.46 212,204.05 G-2 1829 1480 21 2,502,375.05 212,201.11 G-11 1825 1486 22 2,502,378.50 212,198.27 G-lO 1829 1483 23 2,502,381.63 212,195.72 G-17 & RD 1832 1488 24 2,502,382.27 212,199.71 G-7 1832 1484 LEG #l: · LAT = 60050' 23.575" LONG =151°36' 4Z. 505" ' 2,502,455.60 212,226.40 (Reserved for Compressors) 2,502,427. l0 212,301.20 RD&2 LEG #2' LAT = 60°50' 23.313" LONG =151°36' 45.982" 37 38 39 4O 41 42 43 44 45 46 47 48 1906 1880 1574 1878 1882 1886 1886 1884 1880 1876... 1874 1819 1882 18!9 2,502,421.45 212,297.82 G-12, 2,502,424.94 212,294.98 G-31 21.502,429.45 212,295.05 G-4 2,502,432.85 212,297.99 G-1 2,502,433.57 212,302.44 G-9 2,502,431.26 212,306.31 G-18 2.502,427.00 212,307.78 G-14 2,502,422.80 212,306.18 G-30 2;-502,420.60 .......... 2i2,'302.25 .................. GZ8 ~ R ~ I 2,502,425.63. 212,299.39 G-6 2,502,429.40 212,300.83 G-32 2,502,426.27 212,303.38 G-16 : 1458 1 383 1386 1389 1389 1386 1382 1378 1376 ..... 1378 1382 1385 1 383 1381 Atas~a Region April 15, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. A~ckorage, All 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attacked surface survey locations of tl~e "Legs" and conductors for the four platforms in tke Trading Bay Unit as well as tke Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope tkis will meet your needs. Yours very truly, sar . s. Regional Drillin~ Manager GSB/!ew GRAYLING DISTANCE & DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL LEG ~/3: LAT = 60o50' 22.569" LONG =151 °36' 46.519" 2,502,352.30 212,272.70 1804 1 2 3 4 5 6 7 8 9 10 ll 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 G-26 1806 2,502,358.05 212'269.49 G-25 1810 2,502,358.77 212,273.94' G-24 1810 2,502,356.46 212,277.80 G-20 1808 2,502,352.20 212,279.28 1804 2,502,347.99 212,277.68 G-36 1800 2,502,345.80 212,273.75 G-34 & RD 1798 2,502,350.83 212,270.89 G-23 & RD 1803 2,502,354.60 212,272.33 G-33 1806 2,502,351.47~ 212,274.88 G-27 & 28 1803 LEG #4: LAT = 60o50' 22.832" LONG =151o36' 48. 042" 2,502,380.80 212,197.90 1831 13 14 15 16 17 18 19 20 21 22 23 24 LEG #1: 2 · LAT = 60o50' 23.575" LONG =151°36' 47..505" ' 2,502,374.34 212,196.66 G-1 4A 1825 2,502,376.65 212,192.79 G-1 9 1827 2,502,380.90 212,191.32 G-13 1831 2,502,385.11 212,192.92 G-15 1835 2,502,387.30 21 2,196.85 G- 5 1838 2,502,386.45 212,201.28 1837 2,502,382.96 212,204.12 G-3 1833 2,502,378.46 212,204.05 G-2 1829 2,502,375.05 212,201.11 G-11 1825 2,502,378.50 212,198.27 G-lO 1829 2,502,381.63 212,195.72 G-17 & RD 1832 2,502,382.27 212,199.71 G-7 1832 ,502,455.60 212,226.40 1906 (Reserved for Compressors) LEG #2' LAT = 60o50' 23.313" LONG =151 °36' 45.982" 2,502,427. l0 212,301.20 1880 37 38 39 40 41 42 43 44 45 46 47 48 2,502,421.45 212,297.82 G-12, RD & 2 2,502,424.94 212,294.98 G-31 2.. 502,429.45 212,295.05 G-4 2,502,432.85 212,297.99 G-1 2,502,433.57 212,302.44 G-9 2,502,431.26 212,306.31 G-18 2. 502,427.00 212,307.78 G-14 2',502,422.80 212,306.18 G-30 ........... 1 2',-502,420.60 ............ 212','302.25 .................. G'-8 & RD 1 2.~502,425.63 212,299.39 G-6 1 2 ~ 502,429.40 212,300.83 G-32 1 2,502,426.27 212,303.38 G-16 1 1874 1878 1882 1886 1886 1884 1880 876 874 882 FEL _ 1409 1413 1415 1415 1412 1408 1404 1402 1'404 1408 1411 1409 1407 1486 1487 1491 1493 1491 1487 1483 1480 1480 1486 1483 1488 1484 1458 1383 1386 1389 1389 1386 1 382 1~7o 1376 ...... 1378 ..... 1382 1385 1383 1381 REPORT OF SUNDRY WELL OPERATIONS 1. Operations perfOrmed: Operation shutdown [] Stimulate Alter Casing [] Other ~ 2. Name of Operator Union Oil Company of California 3. Address Plugging [] Perforate ~ Pull tubing P.O. Box 190247., Anchoraqe, Ak..~.:, 99519-0267 Attn: C. Loc~ 4. Location of well at surface 1874 'N-1386 'W f/SE Cr., Sec 29, T9N, R13W, S.M. At top of productive interval 625'N-1703'W f/SE Ct., Sec 33, T9N, R13W, S.M. At effective depth 260'N-1364'W f/SE Cr., Sec 33, T9N, R13W, S.M. At total depth 214'N-1316'W f/SE Cr., Sec 33, T9N, R13W, S.M. 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13,800 feet 10,110 feet 13,679 feet 10,005 feet Plugs (measured) Junk(measured) Casing Structural Conductor Length Size Cemented 369' 26" Driven 602' 17-3/4" 775 sx : ..... '-~$,a;fff~ ............. Intermediate 5. Datum elevation (DF or KB) 99' RT above MSL 6. Unit or Property name Trading BayUnit 7. Wellnumber TBUS G-12RD #2 8. Approval number 7'.- 102 9. APl number 50-- 133-20116-02 10. Pool McArthur River Field 13,679' Measured depth WueVerticaldepth 369' 369' 602' 602' 6,OI'3~' 4,~23~?~' Production 1'0,257 ' 9-5/8" Window Liner 4,036' 7" 700 sx Perforation depth: measured 13,265''I3,390'; 12,975'-13,005' true vertical 9,700'-90798'; 9,488'-9,510' Tubing (size, grade and meaSured depth) 3-1/2", 9.2#, N-80, Plastic Coated @ 12,925' Packers and SSSV (type and measured depth) Baker FB-1 @ 1~,~' 12. Stimulation or cement squeeze summary 13. 10,257' 7,43'9' 9,746'-13,782' I0,095' Intervals treated (measured) 12,975 ' -13,005 ' 1987 · ~aska Oil & Gas Cons. Camm;~CfC,~ ~cnorage ..... Treatment description including volumes used and final pressure 33 bbl 5% HC1 & 75 bbl 12% HCl - 3% HF (a 3000 ~si f~na] Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well. operation Subsequent to operation 14. Attachments Tubing Pressure 5584 B/D 2969 psi 2887 psi 6600 B/D 1700 psi 3000 psi Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15.1hereby certify that the foregoing is true and c )rrect to the best of my knowledge ~ ~"'- lJ.,.:'"~ Signed Roberts Form 10-404 Rev. 12-1-85 Environmental Engineer Date 7/7/87 Submit in Duplicate UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO, 1 of 5 LEASE TBUS G-12RD #2 McArthur River Field WELL NO. FIELD DATE 5-8-87 5-9-87 5-10-87 5-11-87 5-12-87 5-13-87 E.T.D. 13,690' 2,050' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Skidded rig over G-12 RD #2 and rigged up. Circulated well with 450 barrels FIW taking returns to production. Set tubing plug at 250'. Well dead, pulled production tree at 2400 hours. Continued pulling production tree. Nippled up and tested riser and BOPE. Tubing hanger not sealing in wellhead. Unlanded hanger and found tubing parted at 374'. Tubing was badly corroded. Calculated top of fish at 417'. Installed test plug in wellhead and tested BOPE equipment. Removed test plug. Made up fishing assembly ~1 and tagged top of fish at 434'. Worked over fish and pulled loose with 15,000# over-pull. POH and recovered nothing. Re-ran tools and tagged fish at 434'. Worked over fish and pulled loose with 25,000# over-pull, gained 10,000# weight. Recovered a 3-1/2" stub and 49 full joints. Total fish recovered in 2 runs 1984.22' (61 joints). Existing fish in hole is a 4.25" buttress collar at 2027'. Redressed overshot with 4-1/4" basket grapple for third run. Tagged top of fish at 2050' Worked over fish and pulled loose with 175,000~. Gained 4,000~ ~eight. POH with fish at 2400 hours. 1,563' Continued to POH with fish. Recovered 11 joints of 3-1/2" buttress tubing (347.11'). Top of fish at 2331'. RIH with 5-1/8" close catch overshot with 4-3/8" grapple. Tagged top of fish at 2387'. Could not engage fish and POH. Made up 8-1/8" overshot ' Q' with 5-5/8" grapple. Tagged fish at 2387'. Could not engage fish I and POH. Made up 7-5/8" overshot with 4-1/4" grapple. Tagged ~ ~i] I fiSh at 2387'. Could not recover fish. Re-ran 8-1/8" overshot I ~%~h 5-5/8" grapple. Tagged fish at 2397'. Worked tools to .... ~I??~7' . POH and had no recovery. Re-ran 8-1/8" tools and tagged .~ .... ~ fish at 2420'. Worked and rotated tools to 2447'. POH and m~;~- : recovered GLM with tubing collars on both ends and a 20" long x 13" wide x 1/4" thick piece of iron wrapped around GLM. Top of fish is at 2339'. Made up 7-3/8" overshot with 3-1/2" grapple. Tools stopped at 1563' POH and inspected tools. Re-ran tools, could not get past 156~'. Rigged up Schlumberger for collar log at 2400 hours. 2,425' 2,725' RIH with Schlumberger 4" collar locator. Unable to get past 1560'. logged from 1560' to surface. RIH with an 8" impression block and tagged fish at 1563'. POH. Waited on tapered mill to be fabricated and delivered. RIH with a 6" bit and 3 each 4-3/4" drill collars. Could not work past 1563'. RIH with tapered mill, bumper sub and jars. Milled for two hours without any progress. POH and found pin on jars had parted. RIH with overshot and grapple and recovered tapered mill assembly. RIH with 8-3/8" mill shoe with 12' extension, drive sub, bumper sub, jars and 12 each 4-3/4" drill collars at 2400 hours. Continued to RIH with 8-3/8" mill shoe and milled from 1563'-1566', recovering 3 pieces of cast iron. Pushed debris to 1581' and milled from 1581'-1583'. Pushed debris and milled to 1692'. Fell free to 2425'. Milled to 2426' and fell to 2452'. Changed out 3-1/2" drill pipe to 5" drill pipe from work boat. Installed 5" pipe rams in single gate. Testing same at 2400 hours. RIH with mill shoe. Milled and worked shoe to 2514'. POH and recovered 202.36' of 3-1/2" tubing. Theoretical top of fish at 2583.89' RKB. RIH with overshot, hollow mill and grapple. Engaged fish and recovered 141.55' of tubing. RIH with TSA grapple and overshot and engaged fish at 2400 hours. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO 2 of 5 LEASE TBUS ,WELL NO G-12RD :~F21ELD McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5-14-87 5-15-87 5-15-87 5-16-87 5-17-87 5-18-87 5-19-87 5-20-87 3,266' 3,296' 3,629' 5,786' 12,853' 13,218 POOH and recovered 90.58' of tubing. Top of fish at 2816.02'. RIH with overshot and grapple. Caught fish and unsuccessfully attempted to run a 1-11/16" sinker bar into fish on wireline. Pulled 120,000~ over and parted tubing. POH and recovered 449.66' of tubing. Found a piece of junk in top joint of fish. Top of fish at 3265.68'. Leveled rig and made miscellaneous rig repairs. RIH with overshot and grapple. Caught fish. Made a 1-11/16" feeler run to 12,785' through fish. Rigged up 2-19/32" jet cutter at 2400 hours. RIH with2-19/32" jet cutter, stopped at 3266'. POH. Ran cutter with centralizer and also stopped at 3266'. POH. RIH with string shot to 3508' to back-off, misfired. Redressed and re-ran string shot to 3508', misfired. Redressed and re-ran string shot a third time to 3508', misfired again. Performed a blind back-off and recovered 1 joint (30.27'). Top of fish at 3295.95'. RIH with overshot and engaged fish. RIH with APRS 2-19/32" jet cutter, could not get into fish. RIH with 2-3/4" swedge, could not get into fish. RIH with 2-5/8" swedge, stopped at top of fish. RIH with 1-11/16" chisel, stopped at top of fish. Performed blind back-off and recovered 1 joint (31.40'). Top of fish at 3327.35'. RIH with overshot and engaged fish. Jarred, tubing parted. Recovered 10 joints (302.12'). Top of fish at 3629.47'. RIH with overshot at 2400 hours. Circulated at 3620'. Engaged fish with overshot. RIH with 2-3/4" swedge, stopped at top of fish. RIH with 1-11/16" chisel to 12,810'. RIH with 2-1/2" swedge to 3739', could not go deeper. Had same results with 2-3/8" and 2-1/4" swedge. Rigged up Buzz Meyers braided line. RIH with 2-3/4" swedge to 4240', could not go deeper. POH. Performed blind back-off. Recovered 71 joints (2156.38') including GLM #14. Top of fish at 5786'. RIH with overshot and engaged fish. Pressured to 2500 psi and held, no holes in fish. RIH with 2.65" swedge, could not enter fish. POH and re-headed wireline. RIH with 2.65" swedge at 2400 hours. Ran 2.65" swedge to 12,825'. RIH with APRS 2.59" jet cutter on Schlumberger wireline, could not enter fish. RIH with 2.65" swedge on Meyers wireline to 10,590'. Tool stuck when attempting to POH. Dropped "Go-Devil" and worked pipe. Dropped 19', 1-1/2" cutter bar on top of "Go-Devil" wireline at 523'. Pulled tubing free with 189,000~ over tubing weight. Pickup weight indicated all of tubing string was free. POH and stripped 3-1/6" wireline at 2400 hours. POH and stripped wireline to fish. Recovered all 3-1/2" tubing and jewelry Change and tested pipe rams. Picked up 6" bit, ' 7" scraper and 3-1/2" drill pipe while RIH at 2400 hours. Continued picking up 3-1/2" drill pipe. RIH with 3-1/2" and 5" drill pipe equipped with rubbers. Tagged packer at 12,853'. Circulated clean and POH. Repaired drawworks brake mechanism. RIH with TSA shoe and packer mill assembly at 2400 hours. RIH with mill and jars and tagged packer at 12,853'. Milled packer (had very high torque). POH. Mill shoe was 50% worn. RIH with 6" concave junk mill and tagged packer at 12,853'. Lubricated circulating system with MD & XC. Milled packer free in 3-1/2 hours. Chased packer to 13,218'. Worked packer in tight hole. Jars not working. POH at 2400 hours. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO 3 of 5 TBUS G-12RD #2~ LEASE WELL NO IELD McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5-21-87 5-22-87 5-23-87 5-24-87 5-25-87 5-26-87 13,679' 12,850' 13,679' Laid down concave junk mill. RIH with 6" tapered mill. Hit tight spot at 13,218' and milled to 13,221'. Stuck, jarred free. POH with mill. Gauge ring on taper indicated that mill was on packer and also had undersized casing. RIH with flat mill and new jars. Tagged packer or casing at 13,229' and milled to 13,234'. Singled in hole to 13,606'. Plugged water course. Circulated out with Hi-Vis sweep. Pushed packer to 13,679'. Circulated out fill with Hi-Vis sweeps. POH at 2400 hours. Finished POH. Changed out hydromatic pump. Laid down flat bottom mill. RIH with 8-1/2" bit and 9-5/8" scraper. Tagged 7" liner top. Circulated clean and POH. Rigged up Schlumberger and ran 9-5/8" Dia-log multi-finger casing inspection log. Failed due to leaky rope socket, POH. Logged 9-5/8" casing with casing inspection log. RIH with 7" casing inspection log at 2400 hours. Finished RIH with 7" Dia-log inspection tool and stuck at 12,880'. Pulled free and logged 7" casing. POH. Replaced drawworks brake lining and cracked brake bands. RIH with 9-5/8" RTTS and set at 9720'. Tested backside to 2550 psi. Bled to 2400 psi in 30 minutes, bled up drill pipe. ROH and found 3-1/2" x 5" drill pipe cross-over leaking. RIH and set 7" RBP at 12,850' and 7" RTTS at 12,812'. Tested RBP to 3000 psi, OK. Tested 7" x 9-5/8" liner lap to 2550 psi for 30 minutes, held tight. Hold pressure on 9-5/8" casing and rigged up Howco on 9-5/8" x 13-3/8" annulus at 2400 hours. Bled 9-5/8" x 13-3/8" annulus to 0 psi. Pressure built to 80 psi in 20 minutes. Pressured annulus to 2500 psi with 12 barrels (including lines) and held solid for 45 minutes. Rigged up annulus to production and bled to 150 psi in 1 hour and 20 minutes, unable to meter any water or gas rate. Centered derrick over well. Latched on to 7" RBP with RTTS and POH. Made up 4" - 4 HPF Vann TCG, Champ II packer and Omni tool and RIH on 3-1/2" and 5" drill pipe at 2400 hours. Filled drill pipe with FIW to 1150' and dry to surface for 500 psi underbalanced condition. Rigged up Schlumberger and ran GR tool to locate guns, GR failed. POH and repaired GR tool. Located guns and set packer at 12,954'. Verified packer depth with GR. Rigged down Schlumberger. Rigged up Howco, Vann monitor and Fluid Level Services. Pressured up annulus and cycled Omni tool open. Verified with fluid levels. Pressured up annulus and fired guns from 12,975'-13,005' and 13,265'-13,390' DIL. Fluid level rose to 908' and stabilized at 16'/10 minute rate. Cycled Omni valve closed and circulating ports open. Reverse circulated with FIW. Cycled Omni ports closed and valve open. Released packer and reverse circulated. POH at 2400 hours. Laid down guns and test tools (100% of shots fired). RIH and set RTTS at 12,906'. Rigged up Schlumberger and ran a static temp log across perfs. Injected into perfs with 1.5 BPM at 1600 psi. Increased rate to 1.75 BPM at 2200 psi. Final injection pressure at 2400 psi. Ran a profile log (spinner and temp) across perfs. No water entering B-l, most water exiting bad spot in casing from 13,205'-13,220' DIL and B-4. Rigged down Schlumberger. POH with RTTS to prep well for B-1 acid job isolation at 2400 hours. UNION OIL CO. OF CALIFORNIA 4 of 5 DRILLING RECORD PAGE NO. LEASE TBUS McArthur River Field G-12RD #F2 WELL NO IELD , DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DATE E.T.D. 5-27-87 5-28-87 5-29-87 5-30-87 13,050' 13,679' Continued to POH with RTTS. RIH with bit and 7" scraper, bumper sub and jars to 13,055'. Pumped a high viscous sweep and displaced with clean FIW. POH with scraper and bit. RIH with Howco 7" RBP and Champ II packer. Set RBP at 13,050' and packer at 13,030'. Tested between tools to 2000 psi, OK. Released Champ II packer and spotted 3 barrels of 5% HC1 across perfs. Re-set Champ II packer at 12,907'. Hooked up 9-5/8" x 13-3/8" annulus and attempted to pump in. Could not pump more than 7 barrels. Could not break down B-1 perfs at 2400 psi. Spotted another 6 barrels of 5% HC1 across perfs. Re-set Champ II packer at 12,785'. Broke down perfs at 3/4 BPM and 2800 psi. Re-set Champ II packer at 12,907' with bypass open and pumped 24 barrels of 5% HC1 and 75 barrels of 12-3 mud acid followed with 500 gallons of ammonium chloride water. Closed bypass and continued pumping at 3/4 BPM and 2800 psi at 2400 hours. Continued displacing acid at a final rate of 0.4 BPM at 3000 psi. Released RTTS and latched onto RBP, POH. RIH with Baker 7" perm packer with wireline re-entry guide, Otis "X" nipple and 1 joint of 3-1/2" plastic coated tubing. Positioned packer at 12,860', broke circulation and dropped ball to set packer. Set packer with 1000 psi and sheared ball at 3500 psi. POH. RIH with seal assembly on drill pipe. Stabbed into packer at 12,860' and tested backside to 2000 psi, OK at 2400 hours. Rigged up Howco to 9-5/8" x 13-3/8" annulus. Mixed up 5 barrels of FIWwith gel and 10 sacks of barite. With 2000 psi on 9-5/8" casing, pumped 4 barrels of weighted pill down annulus at 2000 psi. Unstabbed from packer and changed well over to clean FIW with Nalco 3900. POH and laid down drill pipe and collars. Installed test plug in wellhead. Tested Hydril to 1500 psi. Found a crack in 13-3/8" casing stub between wellhead bowl and 17-3/4" cut off. Had welder repair crack. Completed BOPE test. Ran in hole with 3-1/2" tubing at 2400 hours. Continued running 3-1/2", N-80 plastic coated tubing with Seal Lock connections. Stabbed into Baker Model FB-1 packer at 12,881' (TBG MEAS.). Established injection rate of 3 BPM with no returns up annulus. Tested backside to 1000 psi. Pressured 9-5/8" x 13-3/8" annulus to 900 psi to check weld, OK. Spaced out and landed tubing on new stainless steel tubing hanger. Tested hanger to 5000 psi, OK. Nippled down BOPE and riser. Installed injection tree and removed BPV. Turned well over to production. Released rig at 2400 hours 5-30-87. dNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO 5 of 5 LEASE TBOS WELL NO G-12RD #~IELD McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 0272N TUBING DETAIL DESCRIPTION Wireline Reentry Guide 5-3/4" O.D. .92 1 Joint - 3-1/2", 9.29, N-80, plastic coated tubing with seal lock 29.18 Otis 3-1/2" "X" Nipple 1.26 X-over .67 Baker Seal Bore Ext. 9.35 Baker 7" FB-1 Permanent Packer 3.35 Baker No-Go Locator .83 1 Joint - 3-1/2", 9.2#, N-80 plastic coated tubing with seal lock conn. Otis "XA" Sliding Sleeve 414 Joints - 3-1/2", 9.2#, N-80 plastic LENGTH FROM 12,926.40 coated tubing w/seal lock conns. 3-1/2", 9.2#, N-80 plastic coated pup joint with seal lock conn. 3-1/2", 9.2~, N-80 plastic coated X butt with seal lock Cameron 11" Stainless tubing hanger Landed below zero 12,925.48 12,896.30 12,895.04 12,894.37 12,885.02 12,881.67 30.35 12,880.84 3.95 12,850.49 12,794.85 12,846.54 6.19 51.69 TO 12,925.48 12,896.30 12,895.04 12,894.37 12,885.02 12,881.67 12,880.84 12,850.49 12,846.54 51.69 45.50 1.60 45.50 43.90 .70 43.90 43.20 43.20 43.20 0.00 Alaska District Unocal Oil & Gas Di~( Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Oune 10, i~87 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Blair, Unocal has recently completed the repair of two injection wells on the Grayling platform. The tubing was replaced in both wells G-16 and G-12 in order to prevent communication between the tuOing and casing annulus. Following completion of the repairs, the tuOing and casing annulus integrity was tested. The attached memo summarizes t~e results of those tests. Sincerely, S A Lambert District Engineer SAL/nc/O395r Attachment cc: V.I. Lytle W.D. Kirchner - MOCO T. Wellman - ARCO RECEIVED Alaska Oil & G&s Con$~ Commission Anchorage i,, Memorandum UNOCAL ) June 3, 1987 TO' S.A. Lambert FROM' J.M. Quintan~~~- RE' Casing Pressureg for G-12 and G-16 The tubing /9 5/8" casing annulus has been pressurized and monitored on both G-16 and G-12. They have been filled with water and a pressure of 1500 psig maintained. A summary of the bleed off tests is as follows' .f'/15/t~?--1) G-16 leaks 25 psi in a 24 hr. period (looses 1½ gal per day). ~/~/1~'/-=' 2) G-12 has held 1500 psig for a 24 hr. period with no loss in pressure. These pressures will be maintained unless otherwise notified. cc' S. M. Wi ese J. T. Beitia RECEIVED ,~,las~(a Oi~ & Gas Corm,, Commissior~ Anchorage FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. flECE'IVED JUN ,n, 1987 STATE OF ALASKA --' ALASK.. OIL AND GAS CONSERVATION COMM.,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing Time extension [] Change approved program [] Plugging [] Stimulate IQ( Pull tubing ~ Amend order [7 Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA 99' RT Above MSL feet 3. Address 6. Unit or Property name P.O. Box 190247, Anchorage,. Ak. 99519-' O247 Trading Bay Unit 4. Location of well at surface Sec 7. 29, T9N, RI3W, SM. At top of productive interval 33, T9N, R13W, SM. At effective depth 33, T9N, R13W, SM. At total depth 33, T9N, R13W, SM. 1874"N - 1386'W f/SE Cr., 625'N - 1703'W f/SE Cr., 265"N - 1369'W f/SE Cr., 214'N - 1316'W f/SE Cr., Sec. Sec Sec Well number TBUS G-12rd 8. Permit number 78-42 9. APl number 50-- 133-20116-02 10. Pool McArthur River Field 11. Present well condition summary Total depth: measured true vertical 13,800feet 10,110feet Plugs (measured) Effective depth: measured true vertical 13,690feet 10,027feet Junk (measured) Casing Length Structural 369 ' Conductor 602 ' Surface 6 ,. 013 ' Intermediate 10,25? ' Production 4,036 ' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Size Cemented Measureddepth ~ueVerticaldepth 26" Driven 369' 369' 17-3/4" 775SX 602' 602' 13-3/8" 2,525SX 6,013' 4,237' 9-5/.8" Window 10,257' 7,439' 7" 700SX 9746-13782 10,095' 13,265 - 13,390'; 12,975-13,005' RECEIVED 9,700 - 9,798'; 9,488 - 9,510' - ,-. B .1 :..;:-': 1:9 8 7 3-1/2", 9.2#, N-80 @ 12,941'/daska 0it & Gas Cons. Anchoraqe Baker F-1 8 12,882'; Camco TRB-6 8299' 12.Attachments Description summary of proposal~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 3-22-87 14. If proposal was verbally approved Name of approver , / Date approved 15. I hereby certify that the foregoing is true and~¢to the best of my knowledge Signed ;4~::t'..'.;/.,~;/:r ~','-2. C'/:':,~;? Robe'~rt s ~itle ENVIRONMENTAL ENGINEER ' r/"~Y' Co~mission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Date Approved by Form 10-403 Rev Commissioner the commission Date Submit in triplicate TBUS G-12 RD #2 PROC EDURE: 1. Move over TBUS G-12 RD #2, leg 2, slot 37 and rig up. 2. Kill well. Remove tree, install and test BOPE. Cannot set BPV due to threads in hanger are corroded away (will set tubing plugs if feasible). 3. Spear 3-1/2" tubing in tubing hanger and pull above rotary table. 4. Pull and lay down .3-1/2" tubing string. Tail at 12,941'. 5. Mill over and recover Baker Model F-1 perm packer at 12,864'. Correct 13-3/8" X 9-5/8" annulus pressure as follows: Test casing to 2500 psi. If casing tests, attempt to pump down 13-3/8" X 9-5/8" annulus establishing rate below shoe fracture pressure. If rate can be established and fluid flow determined, attempt to p~np cement down annulus from surface to shoe. If casing does not test, locate hole in casing. If hole is b~low 13-3/8" shoe, squeeze as required. If hole is above 13-3/8" shoe, attempt to circulate cement down casing and up 13-3/8" X 9-5/8" annulus to surface. 6. Clean out and test squeezes and casing again if needed. 7. R~n casing inspection log in 7" and 9-5/8" from 13,000' to surface. 8. Reperforate Hemlock Bench 1 and 4 (12,975'-13,005'; 13,265'-13,390' MD). 9. Acidize Hemlock Bench 1 with 1500 gal. mud acid. 10. Run single 3-1/2" Hemlock injector completion assembly. 11. Remove BOPE, install and test tree. 12. Put well on injection. DAS: gr 0339D .~. ~.-. "~--~. ANGLED FILL UP LINE HYDRIL - ~,~ ~0 ' ' PIPE RAMS ' "" o . . ~ ~ VALV~ . -~- ....... · -~, ~ j~:o:~ii J l ~ ~. , K,~ LiNE ~ J ' ~ -- ~ I J ~~OM MUD PUMPS ~ ~. & CEMENT UNIT OPERA TOR FURNISHED' WELL NAME: RIG CONTRACTOR: RIG: STACK PRESSURE CHOKE LINE SIZE & MSP: NOTES:'1.. HYDRAULIC VALVES OPEN AUTOMATICALLY WHEN DIVERTER IS CLOSED, FLEX HOSE ~'/~ tS TO BE tF ~ECESSARY '"'""" , .. ,,, ~ n _, ALL '" ' ' '" """" ~ Q ......HAVE ~,,~;~ ........ ,, i-[,, , ~r~ APPROVAL DR~L~iN~ DISTR,~-, SUPERINTENDENT BY THE '"~ ' ' DEPT. APPROVAL " ,--' ,.JO ~ ,,,~,.~;,,.,~ Oil & uas Cons. COiI'IITiJSSiO,q, Anchorage ,,. ,,. ~-~ ~. ~ 1 I 5~ OR l OM ~~ A~ WORK~.-n ~PE~T~ONS .... . . . l'lI I -- -- R~..." 1 itl I 7: ':'q rlF ' .... STATE OF ALASKA ALASK,.-, tJIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. UNION OIL ~COMPANY OF CALIFORNIA 78-42 3. Address 909 W. 9TH AVE., P. O. BOX 6247, ANCHORAGE, AK 4. Location of Well 99502 £ond. #37' Leg #2, 1874' N & 1386' W of SE corner, Sec 29' T9N, R13W, S..M. 5. Elevation in feet (indicate KB, DF, etc.) 99' RT above MSL 6. Lease Designation and Ser'ial No. ADL- 17 594 8. APl Number 5o- 1 33-201 62-02 9. Unit or Lease Name Trading Bay Unit 10. Well Number TBUS G-12RD2 11. Field and Pool' McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Pr~oposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were reperforated in 1/81- 12975' - 13005' 13265' - 13390' Bench 1 Bench 4 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ TitleDistrict Engineer i / ~--~ ._~__ The space fol~l~°r~'~i~s~? use Date May 24, 1982 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10-73 Submit '*1 ntentlons' In Triplicate & "Subsequent Reports" in Duplicate STATE OF AI.ASIGA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OwlELLLr~WELLGAS r"~ OTHER 2. NAME OF OPERATOR Union 0il Company of California ADDRESS OF OPERATOR P.O. Box 6247, Anchorage, AK- 99502 4. LOCATION OF WELL At surface Cond' #37' Le9 #2, 1874' Sec, 29, 19N, R13W, S.M. N & 1386' W of SE corner 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT above MSL 14. Check Appropriate Box To lndi~cate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20116-02 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBUS G-12RD~ ~. 10. FIELD AND POOL, OR WILDCAT McArthur Ri'ver Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, TgN, R13W, S.M. 12. PERMIT NO. 78~42 3ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Rp,n~rf pyistfng intervalq SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly stateall pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. ~ It is proposed to reperforate the following intervals' 12975 13005 Bench 1 13265 - 13390~ Bench 4, Su}:,:equent Work Ileported on Fm'm No./_~~Z3Dated~t2~.~Z RECEIVED JAN2 2 1981 0it & Gas Cons. C0mmissi0n Anchorage I hereby ce~r~ is true and corrocti SIGNED ~ .~ "~ - C.H. Case (~hls space for State 0f fl/~e~.u se)~../;.. ~- , APPROVED BY ·/(~'~ ~-~ :~ TITLE CO.DmONS OF A...OVAL, ~F a~v;-~B~l C~I~R OF THE CO~ISSION TITLE Distric$ Enaineer DATE- 1/20/81 See Instructions On Reverse Side DATE /-z 3 Approved Returned VVEt. I. '",, COF,'I3 ['AC c)l SI'LTl) l~;\Tl,; .5-18-78 CO~I['. DATH 7'21-78 CO-~.[,[:...,,CTO;~ PARKER j[[~; ;~{,~ · rY['?: u::i'r i~2o NATION DI'E~~~C ...... DI{[I..L t'IPi': I);,',~;CIi[['TION_ [;:.:AGE __Z~G_IB~IT STAT.E. V,'ELI, NO. G- 12RD2 ?I £{.D.. _~'lc&g T_H9 R__R_I.. VER LCC,\TtO:'[ Conductor 37. L~ilg 2 GRAYLING Platform 1874'N .& 1386'W of SE Corn of Sect 29 T9N R 13W S.M. SERIAL No..ADL 17594 T.V.D. 1O,lll IUD GRAHAM - WATSON PERM. IT NO 73-42 T.D' 13,800' TMD DEVIATION (B.H.L.) COMPANY EL[',~;,IiO,:o: \,'Alu. it I)i']i'Ti[!25' IL T. TO OCEAN FLOOR 224.1 B.T. TO ~ILL\V 99' Iht. TO DR[I,L DECK 19.3.' 5o P OUUC m ,D. "' T CASING & TUi3ING RECORD SIZE I V.'E[GHT 26' tl/2" Wal 17 2/4"} . 312" Wa 13 3)8"t 61# 9 5/8"! 40-43 1/ l& 47# 7" 29// ,3.,, 1/2" 9.2# . . ..... THREAD 'l Sl.ip Join Buttress !Buttress Buttress Buttress ...,DATE -. 6-28-7~ !65' 13,390' to 13, GRADE t Spiral Wel J-55 N-80 & P-110 N-80 N-80 . 13678' F · t 369' DRIVEN 602' Cmt'd w/ 775 sxs 6013' Icmt'd w/ Z5Zb sxs 10257'IWind°w 10257' to 10313 Shoe @ 12697' 13782' ITop La' 9/~R' Cmt'd w/ 700 sxs _1~9f!C_j ln2ection Tubing .. c. nc ~.~.~.~ RECORD InjeCtion See G-12 and G-12RD#1 Hi~f~e~6r abandoned Peri Intervals Hemlock.- Open for Injection INITIAL PRODUCTIO!q' - b.'-_TE "r?T.:+AL i ,_':-:vo:L'l CUT tORAV, i C.p. ! T.P. } ;~- '" Ci{O;:~ ! ;,~C~ (;:OR .1' t · __ _ I , . WPiLL_ HEAD A_S..DEbtD_LY TYPE:, . SHAFFER & CAMERON CASING ~EAD' SHAYFER 12" 3000 ~si.- 13 3/8" S,O.W. CASING HANGER: SHAFFER 9 5/8" SLIPS CASING SPOOL: TUBING HEAD: CAMERON 12" 3000 psi x 12" 3000 CAMERON 12" 3000 psi x lOt' 5000' DCB Spool TUBING IIANGER: TUBING IIEAB TOP: 3 1/2" EUE' CAME RbN Si ngl e 3 1/2" · MASTER VA[,VES:...Single MASTER & SWAB VALVES CItR!:-;T?.IAS TREE TOP CONN.:_ 3_1/2" EUE S EE7 D PAGE LEASE TRADING BAY UNIT STATE FIELD McARTHUR RIVER BATE ETD 1 5/5/78 2 5/6/78 3 5/7/78 4 5/8/78 5 5/9/78 13,710'TD 12,700'ETD (cmt) 9 5/8' window 12,420'- 12,480' 7" liner 13, 12,272' (7" tie back to surface) 13,710'TD 12,700'ETD (cmt) 9 5/8'! window 12,420'- 12,480' 7" liner 13,70!'- 12,272' (7" tie back to surface) 13,710'TD 12,700'ETD (cmt) 9 5/8' 13,710'TD 12,700'ETD (cmt plug) 9 5/8" window t3,710'TD t2,700'ETD (cmt plug) 9 5/8" wind, w 12,420'- 12,480' 7" stub @10,386' DETAILS OF OPEP~ATIONSo DESCRIPTIOilS 2, RESULTS RU rig 54 over conductor 37 in leg room 2. Loaded 3 1/2" x 7" annulus w/ FIW and circ. hole down annulus w/ returns out tbg until rec. clear water returns. Installed BPV & remove~ CIW 3 1/2" double valve single block X-mas tree. Installed and tested to UOCO specs 12" 3000 psi BOPE. Pulled 3 1/2" seal assy out of perm pkr @ 12,800' and circ. hole w/ FIW. Pulled and LD 423 jts 3 1/2" tbg w/ G.L. mandrels. Loaded tbg & X-mas tree on boat and sent to beach for inspection & repair. Ran 6" bit, 7" csg scraper & three 4 3/4" DC on 3 1/2" G.E. & S-135 DP to perm pkr @12,806' DPM. Circ. hole w/ FIW and POOH w/ DP. Hole taking +50 bbl/hr FIW. Ran 7" HOWCO cmt ret on 3 1/2" DP' and set @12,750'. Tested 7" csg above ret to 1500 psi. Squeezed for abandonment Hemlock Benches 1-4 perfs 12,902'-13,356 w/ 250 sx C1 "G" w/ .75% D-31 to a final pressure of 3500 psi. Pulled out of ret and dumped 10 sx cmt on ret. from 12,750'-12,700'. Pulled DP to 12,700' and rev. hole clean. Finished reversing out from 12,700' after squeeze job and POOH.· Ran Tri-State 7" mechanical inside casing cutter on 5" DP and cut 7" csg @10,406'. Closed BOPE and unable to break circ. thru 7" x 9 5/8" annulus @2500 psi. Cut 7" csg @10,4o7' and unable to break circ. POOH and found blades on cutters rounded and worn out indicating no cut on csg. Redressed cutter and RIH on 5" DP. Cut 7" csg @10__~,38___6t and unable to break circ. thru 7" x 9 5/8" annulus @3000 psi. POOH and cutter o.k.- indicated cut on 7" csg. Picked up-BOPE. Ran Tri-State 7" Model B casing spear and engaged 7" csg. Picked up on csg @300,000# hook load and removed slips. Slacked off on 7" csg and released spear. POOH w/ spear aft'er removing °7" csg slips. Removed CIW 10" 5000 x 12" 3000 psi DC tbg spool. NU 12" 3000 psi spacer spool and 12" 3000 psi BOPE. Tested BOPE to 3000 psi w/ 200 psi leakoff in 5 min (csg leak in 9 5/8" csg @26965').. Dialog perf 7" csg w/ 4 holes @10,348'. Ran 7" spear and engaged 7" csg. Unable to break circ down 7" csg thru 7" x 9 5/8" annulus @3000 psi. Pressured 7" csg to 2000 psi and pulled csg up hole w/ 420,000# hook load. Pulled and LD 3 jts. 7" csg w/ max of 550,000# hook load and 2700 p~i on csg. SIqEE1- D PAGE I' O, UHIOI' OIL CQ'.'P/V.h' O.= CALIFOR IIA ,ELL I ECO . . FIELD . 6 5110178 7 5/11/79 8 5/12/78 9 5/13/78 10 5/14/78 11 5/15/78 13,71'0 ' TD 12,700 ' ETD (cmt plug) 9 5/8" windo' 12,420'- 12,480' 7" csg stub @10,386 ' 13,710'TD 10,345' (cmt ret) 9 5/8" windo' 12,420'- 12,480' 7" csg stub @10,386' 13,710'~D 10,345'pBTD (cmt ret) 9 5/8" windo' 10,257'- 10,262' 13,710'TD 10,345'PBTD (cmt ret) 9 5/8" windo' 10,257'- 10,262' 13,710'TD 10,345'PBTD (cmt ret) 9 5/8" windo' 10,257'- 10,262' 13,710 ' TD 10,345 ' PBTD (cmt ret) 9 5/8" windo' 10,257 ' -10,2 D.c..TA,,L,.~ OF OPEP. ATIONS DESCRIPTIOilS ~, RESULTS Continued to pull and LD 7" csg @450-500,000# hook load holding 2700 psi on 7" csg for total of 28 jts (~9200") Pulled and LD total of 66 jts (~7600') @450-500,000# hook load without pressuring csg. Broke circ. down 7" csg. and thru 7"'x 9 5/8" annulus @7600' and circ hole clean w/ FIW. Finished pulling & LD total of 248 jts + 2 pieces 7" 29# N-80 csg in excellent condition. RD csg tools. Ran 8 1/2" bit and 9 5/8" csg. scraper on three 4 3/4" DC and 3 1/2" DP. Finished RIH w/ 8 1/2" bit & 9 5/8" csg scraper on 3 1/2" DP to top of 7" stub @10,391' DPM. Circ hole clean w/ FIW. POOH & LD 3 1/2" DP. Ran Eastman gyro survey on Dialog W.L. from 10,391~-600'. Perf 9 5/8" csg w/ 4 holes @10,370'. Ran 9 5/8" HOWCO cmt ret on W.L. & set @10,345'. Finished POOH w/ W.L. after setting 9 5/8" cmt ret. @10,345'. Ran Howco stinger picking up 5" DP and stabbed into ret. @10,345' Squeezed holes @10,370' for milling section w/ 250 sx. C1 "G" w/ .75% D-31, .3% D-19, .1% D-6 & 10% sand to a final pressure of 3850 psi. Pulled out of ret and rev. hole clean POOH. Perf 9 5/8" csg w/ 4 holes @10,280'. Ran 9 5/8" HOWCO RTTS retrievable pkr on 5" DP to 210,000' and WOC. Squeeze @10,370' for total of 12 hrs. RIH & set RTTS @10,114' Broke down squeeze perfs @10,280' @3000 psi and PI @6 CFM & 3000 psi. Squeezed perfs @10,280' for milling section w/ 150 sx. C1 "G" w/ .75% D-31, .3% D'19, .1% D-6 & 10% sand to a final press, of 4200 psi. Squeeze held 3950 psi after 35 min. Released press, and rev. hole clean. POOH. Ran 8 1/2" bit & 9 5/8" csg. scraper on 5" DP and drilled out hard cmt. from i0,118'-10,280' (stringers to 10,345'). Circ. hole clean and POOH. Results from Eastman gyro survey run 5/11/78 moved KOP @10,250' apProx. 1100' @S46N. RU Dialog to run Sperry-Sun surface readout gyro survey and could not get tools working in 4 hrs. RD Dialog. Ran 8 1/2" bit on 5" DP to 10,345' and displaced 9 5/8" csg w/ pre-mixed fresh water prehydrated gel-FIW mud. Circ. and cond. mud to +70 vis. POOH. RU Dialog and ran Sperry Sun conventional gyro su--rvey from 10,345'-600'. Ran 9 5/8" Servco section mill & five 6 1/4" DC on 5" DP to 10,257'. Cut 9 5/8" csg. and milled s~ction in 9 5/8" csg from 10,257'- 10',262' in 3 1/2 hrs. Sperry-Sun check gyro confirms KOP location indicated by Eastman gyro. Continued milling section in 9 5/8"'csg from 10,262'-10,269' in 3 1/2 hrs w/ mill #1. Circ hole clean and POOH. Drag increased w/ section mill @+10,150' (100' into 9 5/8" csg) on trip out. Worked pipe and circ bottoms up to clear hole 6' of metal cuttings. Ran 9 5/8" Servco section mill #2 & five- 6 1/4" DC on 5" DP to 10,267'. Reamed 2' to 9 5/8" stub and milled section from 10,269'-10,286' in 9 1~2 hrs. PAGE FLEASE U IIO, I OIL CCF'Bt ',h' OF CALIFO IIA ',ELL i F-CORD · HO, FIELD DATE 12 5/16/7 13 5/17/78 14 6/18/79 15 5/19/78 16 5/20/78 17 5/21/78 13,710 ' TD 10,345 ' PBTD (cmt ret) 9 5/8" windo~ 10,257'- 10,313 ' 13,710'TD 10,100'PBTD (cmt plug) 9 5/8" windo~ 10,257'- 10,313' 10,307'TD 50' Footage 9 5/8" windo~ 10,257'- 10,313' 10,771'TD 464' Footage 9 5/8" windo~ 10,257'- 10,313' 10,771'TD 464' Footage 10,771'TD 464' Footage 9 '5/8" windo~ DETAILS OF OPEP~qTIONS, DESCRIPTICiIS ~ RESULTS After milling 9 5/8" section from 10,269'-10,286' w/ mill #2 circ hole clean and POOH. Drag increased w/ section mill @ +--10,150' (100' inside 9 5/8" csg) on trip out. Worked free by working pipe and pumping bottoms up. Ran 9 5/8" SERVCO section mill #3 and five - 6 1/4" DC on 5" DP to 10,285'. Reamed 1' to 9 5/8" stub and finished milling section from 10,286''10,313' in 7 1/2 hrs. Total 9 5/8" section 10,257'-10,313' (56'). Circ hole clean and POOH. Ran ~300' 3 1/2" DP open ended stinger on 5" DP. Finished RIH w/ +300' 3 1/2" DP open ended stinger on 5" DP to cmt. ret. @10,345' in 9 5/8" csg. below stub. Circ. bottoms up and displaced 9 5/8" csg. w/ FIW. Spotted 125 sx. C1 "G" cmt' w/ .75% D-31 and 10% sand mixed @120#/cu.ft. from 10,345' to +_10,100'. Pulled DP to 10,000' and 'squeezed 10 culft, cmt. away to 1000 psi. Bled off pressure and POOH. Set 9 5/8" Baker ret BP @576'. Tested 12" 3000 psi BOPE to 3000 psi as per Union specs. - test witnessed by DOG representative' Retrieved BP. Ran 8 1/2" bit & five 6 1/4" DC on 5" DP and CO cmt. in 9 5/8" csg. from 10,081'-10,100'. Continued dressing off cmt. KO plug in 9 5/8" csg. from 10,100'- 10,227'. WOC total of 24 hrs and finished dressing off plug to 10,262' (5' below top of window). Circ hole clean and POOH. Ran 8 1/2" bit & DD BHA #3 on 5" DP to 10,250'. RU Eastman DOT steering tool on Dialong W. and oriented tool fo~ 'left hand turn @ 80 deg. left from high side of hole. DD 8 1/2" hole from 10,262'-10,307'. Displaced FIW in hole w/ fresh water prehydrated gel-FIW system while DD @10,277'. Continued DD 8,1/2" hole 10,307'-10,320' to kick off through 9 5/8" wondow. POOH for new bit. Ran 8 1/2" bit #7 & DD BHA #4 on 5" DP to 10,320'. RU Eastman DOT steering tool on Dialog W.L. and oriented tool for left turn~@70 deg left of high side of hole. DD 8 1/2" hole 10,320'-10,370' and POOH for follow-up assy. Ran 8 1/2" bit #8 & follow up BHA #5 on 5" DP. Reamed DD hole 10,257'-10,370'. Drld & surveyed 8 1/2" hole 10,370'-10,551' & POOH for DD. Ran 8 1/2" bit #9 & DD BHA #6 on 5" Dp to 10,551. RU Eastman D.O.T. steering tool on Dialog W.L. & oriented tools for left turn @80. deg. left of high side of hole. DD 8 1/2" hole 10,551'-10,610'. POOH fbr follow-up BHA. Ran 8 1/2" bit #10 & follow-up BHA #7 on 5" DP and reamed DD hole 10,551'-10,587'. Reamed thru tight spot @10,560'-10,565' second time ~nd stuck 'pipe - jarred free in 1 hr. Reamed DD hole 10,551'-10,610!. Drld & surveyed 8 1/2" hole 10,610' - 10,771'. SP, EE7 D PAGE I'b, D~TE UNIOI'I OIL COt"IPA .ff OF CALIFOPCIIA I',IELL I',ECORD · ,£LL FIELD · DETAILS OF OPEP~qTIONS, DESCRIPTIOilS ~, RESULTS 18 5/22/ 10,997'TD 226' Footage 19 5/23 ll,216'TD 219' Footage 20 6/24/78 11,458'TD 242' Footage 21 5/25/78 11,458'TD 0' Footage 22 5/26/78 11,458'TD 0' Footage 23 5/27/78 11,594'TD 136' Footag~ 24 5/28/78 11,656'TD 62' Footage 25 5/29/78 11,782'TD 126' Footag, 26 5/30/78 ll,920'TD 138' Footag~ Continued drlg & surveyed 8 1/2" hole w/ bit #10 & BHA #7 10,771'-10,775'. POOH to lock up BHA. Ran 8 1/2" bit"#11 & locked BHA #8 on 5" DP and reamed DD hole 10,257'-10,370' & 10,551'-10,'610'. Drld & surveyed 8 1/2" hole 10,775'-10,997'. POOH for DD to turn course left. Ran 8 1/2" bit #12 on DD BHA #9. Finished RIH w/ DD BHA #9 to 10,997'. Ran Eastman DoO.T. steering tool on Dialog W.L. and orient for left turn @80 deg. left of high side of hole. DD 8 1/2" hole 10,997'-10,087' and POOH. Ran 8 1/2" bit #13 & locked BHA #10 on 5" DP-and reamed DD hole 10,997'-11,087'. Drled & surveyed 8 1/2" hole 11,087'-11,216'. Drld & surveyed 8 1/2" hole from 11,216'-11,236' w/ bit #13 & BRA #10. POOH for new bit. Ran 8 1/2" bit #14 & BHA #10 on 5" DP and drilled from 11,236'-11,458'. Dropped survey and POOH. Had some excess drag on trip out. RIH to 5000' and circ. to cond. mud. .. RIH w/ 8 1/2" bit #15 & BHA #11 to 5000' and circ out cond mud. Pilot tests on mud indicate contaminant in system. RIH to 10,200' and circ to cond mud. Mud failing to react to chemical treatment for contamination. Circ & cond mud @10,200'-mud failed to respond to chemical treatment for contamination. Built new fresh water prehydrated gel mud in surface system and displaced hole w/ new mud. Circ & cond mud to 70#/cu.ft. wt, 25#/bbl CEC & 10 CtEL in 12 hrs.' RIH & washed and reamed as necessary @10,648'-10,716', 10,910'- 11,014', 11,099'-11,202' and 11,229'-11,458' in 5 hrs. Drld & surveyed 8 1/2" hole w/ bit #15 & BHA #11 from 11,458'-11,594' in 7 1/2 hrs and bit locked. Pulled into 9 5/8" csg @10,257' & circ to' cond mud for survey by diluting w/ FIW a~d SAPP. Staged in hole to 11,594' w/ no problems and circ bottoms up. Ran W.L. directional survey and POOH for new bit. RIH w/ 8 1/2" bit #16 & BRA #11 on 5" DP - hole in good cond. Drld 8 1/2" hole 11,594'-11,656'. Drilled 11,656'-11,750' in 8 1/2 hfs and lost pump pressure. POOH to washout in slip area of 34th jt 5" S-135 DP (~1,060'). LD washed out jt and RIH to 11,750'. Circ bottoms up and ran W.L. directional survey. POOH for DD. Ran 8 1/2" bit #17 & DD BRA #12 On 5" DP to 11,750'. RU Eastman DOT steering tool on Dialog W.L. and oriented tool to 80 deg. left from high side of hole for max left turn. DD 8 1/2" hole in 11,750'-11,782' in 3 1/2 hrs. Continued DD for maximum left hand turn from 11,782'-11,797'. (Total DD Run #5 11,750'-11,797' - 47' in 5 hrs). POOH w/' DD. TIH w/ 8 1/2" bit #18 on follow-up BHA #13. Reamed DD run & 'drld 8 1/2" hole to 11,920'. Dropped survey & POOH - hole tight @11,824'. TIH w/ 8 1/2" bit #19 (Smith F-2) on BRA #13. PAGE LEASE OIL CCI'?PAM' OF CALIFO IIA IfCORD . . . NO', FIELD DATE ETD 27 5/31/71 28 6/1/78 29 6/2/78 30 6/3/78 31 6/4/78 32 6/5/78 33 6/6/78 34 6/7/78 35 6/8/78 36 6/9/78 37 6/10/7 38 6/11/7 12,147'TD 227' Footage 12,227'TD 80' Footage 12,345'TD 118' Footage 12,487'TD 142' Footage 12,631'TD 144' Footage 12,877' TD. 246' Footage 13,132'TD 255' Footage 13,339'TD 207' Footage 13,586'TD 197' Footage 13,800'TD 264' Footag~ { .l'3,800'TD 0' FoOtage 3 13,800' TD 0' Footage DETAILS OF OPEP~%TIONS, DESCRIPTIO~IS g RESULTS Completed TIH w/ Bit #19 on BHA #13. Drld 8 1/2" hole from 11,920'-12,147' (Smith F-2 Bit 227' in 11 1/2 hrs = 19,J'/hr). Ran survey @12,147'. Instrument depth 12,102' 41 1/2o S36oE. Hole had turned back 5o right in 227'. POOH. PU 8 1/2" Christensen MD-41 S.T. Diamond Bit #20 on BHA #14 & TIH for DD run #6. Completed TIH w/ Bit #20 on BHA #14. CO to bottom 12,132'- 12,147'. RU Eastman D.O.T. steering tool on Dialog W.L, & oriente. DD run #6 to 85o left from high side of hole. DD 8 1/2" hole 12,147' to 12,227' (80' in 10 hrs) D.O.T. tool failed @12,227'. POOH w/ DD (encountered excess drag @12,000'. Broke circ @12,000' & reamed hole). LD DD & PU BHA #15 & bit #21. Completed RIH w/ Bit #21 & BHA #15. Directionally .drilled 8 1/2" hole 12,227'-12,345' (6 hrs). POOH for BHA change~ PU BHA #16 & Bit #22. TIH. Directionally drld 8 1/2" hole 12,345'-12,487'. POOH for DD Run #7. PU DD, BHA #17 & Bit #23. TIH. RIH w/ Eastman DOT steering tool on' Dialog W.L. & oriented DD #7 80o left from high side of hole. DD 12,497'-12,540'. POOH. RIH w/ Bit #24 & BHA #18. Drld 8 1/2" hole 12,540'-12,631'. Finished POOH. PU BHA #19 & Bit #25. RIH. Drlg 8 1/2" hole 12,631'-12,877' (13 1/2 hrs). POOH. .. Finished POOH. RIH w/ Bit #26 & BHA #19. Drlg 8 1/2" hole f/ 12,877' - 13,132'. Dropped survey. Finished POOH. RIH w/ Bit #27 & BHA #20. Directionally drld 8 1/2" hole from 13,132'-13,339'. (10 hrs). Experienced high' torque 13,314'-13,339'. POOH. PU Bit #28 & BHA #21. Finished RIH w/ Bit #28 & BHA #21. Directionally drld 13,339'-13,519'. POOH. RIH w/ Bit #29 & BHA #22. Directionally drld 13,519'-13,536'. Drld 8 1/2" hole frOm 13,536'-13,725' w/ Bit #29 on BHA #22. (206' - 7 1/2 hrs : 27.5'/hr - Smith F-2 Bit). TIH w/ 8 1/2" Bit #30 on BHA #22 -.hole cond. good. Drld from 13,725' to TD @13,800'. (75' - 4 hrs = 19'/hr - Smith F-2 Bit). Made wiper trip - hole cond. good. ... Cicc. & cond. mud to log. D~opped survey & POOH. RU Schlumberger Ran DIL-GR log. Schlumberger checked Driller's TD of 13,800' @13,797' W.L.M. Logged DIL-GR froTM 13,797'-12,450'. Schlumberger unit~ slipped on surface while logging out of hole @12,450'~ good log to 12,450'. Ran DIL-GR back to 13,405' & wall stuck Sonde 13,405'. RU fishing tools, cut & stripped over Schumberger~ Worked overshot over top of Sonde @13,402' DPM. Differentially stuck DP while engaging fish & worked DP free. POOH w/ W.L. & fish on 5" DP. LD fishing tools & fish. ~TE UNION OIL COF'£/V,ff OF CALIFOP 'IIA t ECO D · , HO, FIELD DETAILS OF OPERATIONS, DESCRIPTIO~IS ~ RESULTS 39 6/12/7 13,800' TD RIH w/ BHA #23 & Bit #31. Broke circ. in stages @5,000 0' Footage & 10,000'. Circ. out bridges 13,302'-13,332'. Ran into 13,800' 9 5/8" windiw & circ out gas cut mud (71# In- 61# Out). Circ & cond mud for 7" 10,257'-10 13' liner - mud not responding properly to chemicals. Pulled up into 9 5/8" csg. Circ & cond. mud for 6 hrs. RIH to 13,800'(hole cond good). Circ & cond mud & hole @13,800' for 7" liner. 40 6./13/78 13,800'TD 9 5/8" window 10,257'- 10,313' 7" liner 9746' 13,782' Complt. circ& cond mud. POOH. RU & ran 97 jts 29# N-80 Butt. csg on TIH hydro-hanger. Differentially stuck 7" liner while picking up circ. head w/ liner shoe hung @13,782' (18' off btm). Top of liner hanger @9746'. Liner figures subject to change slightly after DP strap. ·Broke circ& circ 200% capacity of DP & 7" liner - o.k. Dropped shear-out ball to set 7" liner hanger. 41 6/14/78 13,800' TD 13,734'ETD F~ 9 5/8" windo~ 10,257'- 10,313' 7" liner 9746'- 13,782' 42 6/15/78 13,800'TD 13,734'ETD F~ 9 5/8" Hung 7"'liner on TIW hydro-hanger w/ shoe @13,782', F.C. @13,734' & top of tie back sleeve @9746'. Cemented 7" liner w/ 700 sx C1 "G" cmt w/ .75% D-31, .3% D-19 & .1% D-6 mixed @ll8#/cu.ft. Pumped 200 c.f. FIWahead, displaced w/ mud. Bumped plug w/ 2500 psi (displacement high). CIP @03:50 hrs 6/14/78. Released from hanger - had slight flow back. POOH. PU 8 1/2" bit & 9 5/8" csg scraper & RIH & tagged liner top @9746' (no cmt on top of liner). POOH. RIH w/ Baker ret. pkr. & test valve. Set pkr. @9708' ·& opened test valve. Tested liner lap - no good. (Had. hard blow for 10 min). Pulled pkr loose. Pulled up to 9649' & set pkr. RU Howco & established break down rate of 10 CF/ min & 2200 psi. Squeezed liner lap w/ 200 sx C1 "G" cmt w/ .75% D-31, .3% D-19 & .1% D-6 mixed ~lI8/cu.ft. 43. 6/16/78 13,800'TD 13,678'ETI) F~ (corr) 9 5/8' window 10,257'-10,313' Pumped 100 CF water ahead & 50 CF behind. Initial sqz. press. 7" liner 974~'- of 2000 psi and final press, of 3000 psi. ¢IP @03:50 hrs. 13,782' 6/15/78. Held press, on lap until 06:00 hrs (bleed back to 1750 psi). POOH. RIH w/ 8 1/2" bit & 9 5/8" csg scraper. Tagged cmt @9659'. C.O. cmt from 9659'-9746'. POOH PU Baker test-tools. Set Baker test pkr @9636' & opened test tools to dry test lap. No good. RU Howco & squeezed lap w/ 200 sx C1 "G" cmt w/ .75% D-31, .3% D-19 & .1% D-6 mixed @ llS#/cu.ft. Pumped 100 c.f. water ahead & 50 c.~f. behind. Final press of 4500 psi. CIP 10,257'-10,3 3' @07:35 hrs 6/16/78.- Held press on lap 4 hrs. (Press bled back 7" liner 973~'- to 3100 psi). POOH. RIH w/ 8 1/2" bit & 9 5/8" csg scraper. 13,770' (cot) Tagged cmt @9730'. CO cmt 9730'-9734'. POOH. 44 6/17 13,800'TD- 13,678'ETD F~ RIH w/ Baker test tools. Set pkr 9625'. Put 1200 psi gas cushion on DP. Opened tester, bled off DP, had light blow for 5 min then no. blow for 1 hr'.' Pressured'up DP to 3600 psi (bled back to 3200 psi after 30 min - lap - o.k.). POOH. RIH w/ 6 1/8" bit & tagged cmt @9734'. C.O. cmt from 9734'-9904' & fcom 13,638'- 13,678' (TIW plug catcher ETD). POOH. 45 6/18 13,800'TD 13,678'ETD Ft RU Schlumberger. Schlumberger checked ETD FLoat collar @13,678' WLM. Ran FDC-CNL log. RD Schlumberger. RU D.A. Ran CBL, Signature log & Eastman gyro. SEEE-[ PAGE ,LE,-'LSE UNIOI'I OIL OF CALIFOPC.IIA :,ELL ICCORD · .. FIELD ~&TE 46 6/19/78 47 '6/20/78 48 6/21/78 49 6/22/78 50 6/23/78 51 6/24/78 52 6/25/78 53 6/26/78 ETD 13,800' TD 13,678' ETD 9 5/8" wind@ 10,257'-10,3] 7" liner 973z 13,770' 13,800'TD 13,678'ETD 13,800'TD 13,678'ETD F, 13,800'TD 13,678'ETD F( 13,800'TD 13,678'ETD F~ 13.,800'TD. 13,678'ETD F, 13,800'TD 13,678'ETD Fi 13,800'TD 13,678'ETD F, DETAILS OF OPEPJ~TIONS, DESCRIPTIOilS ~ RESULTS RIH w/ Baker ret. pkr. on 3 1/2" DP stinger on 5" DP. Set C pkr @ 13,331'. RU D.A. & RIH 2 3/8" gun on W.L. to 13~10'. Gun misfired POOH. RIH w/ new gun. 1Perf 4 HPF from 13,410'- 3- 13,412' (8 holes). Est. pump in rate of 6 CFM @6500 psi '- (broke back to 3200 psi pumps off). Squeezed perfs from 13,410'-13,4i2' w/ 50 sx. C1 "G" cmt final press, of 7000 psi. CIP @1430 hrs 6/19/78. Rev. clean. PU to 12,650' & set pkr. RIH w/ 2 3/8" gun on W.L. to 13,014'. Gun misfired. POOH w/ gun. Tested sqz. #1 from 13,410'-13,412' @5000 psi. - o.k. RIH w/ 2 3/8" gun & perf 4 HPF from 13,014'-13,016' ( 8 holes). POOH w/ D.A. Set pkr @12,987'. Est. pump in rate of 6 CFM @5600 psi (3700 psi pumps off). Squeezed perfs (Base Hemlock Bench #1) from 13,014'-13,016' w/ 57 sx C1 G cmt w/ .75% D-31, .3% D-19 & .1% D-6. Final press of 6200 psi.- CIP @0305 hrs 6/20/78. Rev. clean WOC 8 hrs. PU to 12,806'. Set pkr & tested sql. to 5600 psi - o.k. RIH w/ D.A. & shot 4 HPF from 12,972'-12,974' (top of Hemlock Bench #1). (8 holes). Set pkr @12,900'. Est. pump in rate of 9 CFM @6400 psi (3200 psi pump off). Squeezed perfs from 12,972'- 12,97~' w/ 100 sx C1 "G" cmt w/ .75% D-31, .3% D-19, .1% D-6. Final press of 5500 psi. CIP @20:30 hrs 6/20/78. Rev. clean. Finished POOH w/ sqz. tools. RIH w/ 6" bit on 90' of 4 3/4" collars. C.O. cmt from sqz. jobs #3, #2 & #1 (i.e. hard cmt. from 12,925'-12,976', 13,000' to 13,060' & 13,320'-13,508' respectively). POOH Set Baker 7" test tool @12,895' above Hemlock Bench #1 & #4. #4 W.S.O. sqz. perfs. Loaded DP w/' 1000 psi water cushion & opened tester - had light blow diminishing for 1 hr. Rev. out & rec. approx. 10 CF excess fluid. Dry test on sqz. perfs - o.k, POOH. Ran 9 5/8" Baker retrievAmatic sqz. tool to isolate & test leak reported in 9 5/8" csg. between 6972' & 6987'. Set tool @7177'. Tested 9 5/8" csg, liner lap & 7" below tool to 3500 psi (100 psi bleed off in' 30 mins) - held o.k. Tested 9 5/8" csg above to 3000 psi - held o.k. Reset tool @6770' (above casing leak) & tested below to ~500 psi. .Bled to 3475 in 30 minS - test o.k. Will eliminate 7" csg tie-back string. POOH w/ 9 5/8" tester. Waited 71 hrs on transportation to haul completion equipment. Changed mud over to FIW @ETD & spotted 50 bbls Dril-S on btm. Ran'& set Baker Model "F" pk~ @12,855' on W.L. (DIL measurements). Changed pipe rams to 3-1/2". Off. loaded prod. equipment. Ran 3 1/2" 9.2# N-80 w/ Atlas Bradford modified couplings. Stabbed into Baker perm pkr 012,855' Otis "X" 012,911', "XA: @12,827', mule shoe @12,941' , Camco TRB-6 ball:valve 0299'. Removed BOPE stack. Installed & tested CIW tree. · S EE7 PAGE LEASE Ui,iIOl'l OIL CO -'PA ,h' OF CALIFOR 'IIA ',ELL I EC0 FIELD · ilATE ETD 54 6~27/78 55 6/28/78 56 6/29/7 57 6/30/78 58 7/01/78 13,800'TD 13,678' ETD 13,800'TD 13,678'ETD F 8 13,800'TD 13,678'ETD F( 13,800'TD 13,678'ETD F( 13,800'TD 13,678'ETD F( DETAILS OF OPEPATIONS, DESCRIPTIOiIS ~ RESULTS RU D.A. vamp flowline. Gas lifted FIW from annulus to GLV #15 (recovered 777 bbls FIW). Put 2000 psi wate? cushion on tbg. Perf 4-1/2" HPF from 13,390'-13,265' w/ D.A. 2 5/8" tbg guns (6 runs - no misfires). SHot all holes with well on gas lift. RD DA. Placed well on production @00:45 hrs 6/29/78 for testing. Shut in well @16:00 hrs 6/29/78. RIH w/ btm hole press recorder to 13,327'. Put well on production for 1 hr drawdown @19:15 hrs. Shut in for build up @21:00 hrs. Completed 24 hr press build up. Opened "XA" sleeve @12,827'. Displaced annulus w/ pkr fluid. Closed "XA" @12,827'. Vamped injection lines Released rig to TBUS G-8RD @12:00 mid 7/01/78. S g_FF D PAGE ~":0, FLEASE TRADING BAY UNIT STATE UHIOrl OIL CCt.:?,c. fY Ccc CALIFO, 'IIA ,'ELL l :ECC,L:,.D l'i~Lb IlO, G-12RD#2 FIELD McARTHUR RIVER DATE FROM 13782.00 13779.60 13736.05 13734.15 13691.79 9779.15 9773.30 9753.10 9745.9O FROM 12441.44 12942.19 12912.24 '12910.84 12882.08 12863.58 12862.75 12830.88 12826.88 12792.75 12785.75 12383.45 12376.45 11978.46 11971.46 11573.12 11566.12 11170.41 11163.41 10729,44 10722.44 10323.34 10316.34 9931.50 9924.50 95'31.67 9524.67 9130.48 9123.48 8522,79 8515.79 7675.67 7668.67 6506.38~ 6499.38 4866.69 4859.69 2377.O3 2370.03 308.35 299.00 40.40 38.85 TO 13779.60 13736.05 13734.15 13691.79 9779.15 9773.30 9753.10 9745.90 = 0 - TO 12942.19 12912,24 12910.84 12882.08 12863.58 12862.75 12830.88 12826.88 12792.75 12785.75 12383.45 12376.45 11978.46 11971.46 11573.12 11566.12 11170.41 11163.41 10729.44 10722.44 10323.34 10316.34 9931.50 9924.50 9531.67 9524.67 9130.48 9123.48 8522.79 8515,79 7675.67 7668.67 6506.38 6499.38 4866.69 4859.69 2377.03 2370.03 308.35 299.o0 40.40 38.85 - 0 DETAILS OF OPEP~TIONS, DESCRIPTIOilS & RESULTS ,, 7" LINER DETAIL LENGTH JTS DESCRIPTION 2.40 43.55 1.90 42.36 3912.64 5.85 20.2O 7.20 9745.90 1 1 94 1 T.I.W. SHOE 7" 29# N-80 Buttress Float Collar 7" 29# N-80 Buttress 7" 29# N-80 Buttress TIW 7" Liner Hanger 7" 29# N-80 Buttress TIW Tie Back Sleeve LANDED BELOW ZERO 3 1/2" TUBING DETAIL LENGTH JTS DESCRIPTION .75 29.20 1.40 28.76 18.50 .83 31.87 4.00 34.13 7.00 402,30 7.0 397.99 7.0 398.34 7.0 395.71, 7.0 433.97 7.0 399.10 7.0 384.84 7.0 392.83 7.0 394.19 7.0 600.69 7.0 840.12 7.0 1162.29 7.0 1632.69 7.0 2432.66 7.0 2061.68 9.35 258.60 1.50 38.85 1 1 12 12 12 12 13 12 12 13 19 20 26 37 54 82 64 8 3 1/2" Mule Shoe 3 1/2" 9.2# N-80 A.B. Buttress OTIS 3 1/2" "X" Nipple 3 1/2" 9.2# N-80 A.B. Buttress Baker 4" x 3 1/2'.' Seal Assy Baker Locator 3 1/2" 9.2# N-80 A.B. Buttress Otis 3 1/2" "XA" Sleeve 3 1/2" 9.2# N-80 A.B.,. Buttress Otis RW4 GLM#1 3 1/2" 9.2# N-80 A.B. Buttress Otis Rw4 GLM #2 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #3 . 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #4 3 1/2" 9.2# N-80 A.B, Buttress Otis RW4 GLM #5 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4'GLM #6 3 1/2" 9.2# N-80 A.B. Buttress .Otis RW4 GLM #7 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #8 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #9 $ 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #10 3 1/2" 9.2# N-80 A,B. Buttress Otis RW4 GLM #11 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #12 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #13 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #,14 3 1/2" 9.2# N-80 A.B. Buttress Otis RW4 GLM #15 3 1/2" 9.2# N-80 A.B. Buttress~ Camco TRB-6 Safety Valve 3 1/3" 9.2# N-80 A.B. Buttr6ss CIW Hanger w/ 8RD X Butt X-Over LANDED BELOW ZERO · i ii i iii iii i i iii i iiii i i iiii ~ I "- 'j ......... '~'/F~' o,.¢~.~so ~. ,, ,, ,J , ~ ~ ~J - ~ ..... ~' I , I I I i ~ ~ ~ [ ..... . , . ' ,, ,, j ~ i ......... ,, ~ t~' o~~" ' ! qn~9' I ..- ~s~~ ~o~' _ ~ ~T ~ I , ....................... il t m ~. DATE ' ...... O~WM s ~ UN~ON OiL 'COMPANY OF C%LI~RNIA " SHE~S j ~HE~ i i ii i i m ~11 i ii I nl i L I FORu 247 (NEW il =---- .LE.O. BIT RECORD ! ~°%°o. ' ?\'~(~ ~' '~ ~' ~'~. RIG NO ~A RIG MAK~ ~ ~ ~ COLLARS: OD X ID X L~ . '~ · " ~, MO. / DAY / YR. ~T.P.-DRtLLERS STATF [~ ~ '~ COUN~ PU~P ~. 2 ki - T~U~ )RILL PIPF ~ UNDER ~NtEr. ' _/ / WATER 50U~ T'~IP/~NGF ' MUD TYPF T~L JOl~ : TOTAL DE~H / / FUEL SOURCF JETS- 32rids ~ DEPTH PER HOURS I~ R.P.~. PRESS. Liner SP~ Liner SPM Wt. ~L.F.V. P.V'Y.P T B ':.~RUN SIZE ~AKE TYPE ' SERIAL Reg. R or RO OUT FEET HOURS FE~ CUM. ~' PU~P PU~P NO1 PUMP NO. 2 ~UD PROPERTIES )ev. DulI. Cond. l~ !/8 Dote NO. NO. ~ I 2 3 HOUR LBS. '1~' " " " z~v~t ~/ce~4'13c 2~1~7*z4o 9o ~u,~,'~ ,.'' ~8 ,' .s~fil~s~ ~4~or /o to 8~q~o t23 ~~.~ ~ mqo /~-~~," 7ot~l~ '~~ ru~ I { t U~d . ' ~" ~ 713 ~ Triplicate. Form G E T ~ I N Y O U R I L L I N G Form No. SES 51 (Rev. 9/65) L ;?~.' ;:f-, .y.: . CONTRACTOR. RIG NO.. RIG MAKF COLLARS: OD X ID X LENGTH MO. / DAY /' YR. T,PJDRILLERS COMPANY FIELD. RIG SIZE ~X. X__ SPUD LEASE , WELL NO. ~ t,~. ~ ~ ~ PUMP NO., .X X UNDER SURFACE / / STATF , COUNTY PUMP NO. 2 DRILL PiPE : ~ UNDER INTER. ~/ / wATER SOURCF SEC./ T'SHIP/RANGE. MUD TYPE TOOL JOINT TOTAL DEPTH ~/ / ~UEL SOURCF J Ver. JETS - 32nds FEET WT. PUMP PUMP NO 1 PUMP NO. 2 MUD PROPERTIES Dev Dull. Cond. l~ 1/8 Date ~.. SIZE MAKE TYPE SERIALNo. Reg.1 2R or R03 DEPTHouT FEET HOURS PER HOuRsCUM' 1000 R.P.M. PRESS. HOUR LBS. Liner SPM Liner SPM Wt. W.L.F.V.P.V?Y.P.. T B : ............................ .... Triplicate Form i: G E T I N Y O U R D R I L L I N G";t', !: Form No. SES §1 (Rev. 9/65) .,. ...... . ...... .~!'., : '-~:i.,: ' .', . ..'. -?:: ~, ::5> . · · ..!!? '": ', September 14~ 1978 UNION OIL COMPANY PoOo Box 6247 Anchorage, Alaska 99502 Reference: TBUS G-12 #2 Gent lemen: This report contains a summary of the drilling mud costs on the well referred to above. The record of drilling mud tests is provided for your information and is representative of the tests made on the mud system during the drilling of the well. The well cost summary and engineering report is filed in our Houston office. Should you require additional information, we will be pleased to furnish it. We look forward to an opportunity to serve your future needs with a complete line of drilling muds and services. Very truly yours, Marketing Administration IMCO SERVICES Division of HALLIBURTON Company 2400 West Loop South · P. O. Box 22605 · Houston, Texas 77027 · 713/622-5555 · Telex: 76-2433 ° Cable:IMCOSER' A Division of HALLIBURTON Company 2400 West Loop South, R O. Box 22605 Houston, Texas 77027 A/C 713 671-4600 WELL DATA SUMMARY COMPANY UNION OIL COMPANY ADDRESS Anchorage, Alaska REPORT FOR MR. WELL NAME & NO, TBUS G-12 #2 STATE I COUNTY Alaska Kenai IMCO WAREHOUSE X Kenai CONTRACTOR PARKER DRILLING ADDRESS REPORT FOR MR. FIELD Trading Bay DESCRIPTION OF LOCATION Grayling Platform WELL DATA DATE SPUDDED CSG. SIZE FROM TO HOLE SIZE FROM TO 5-13-78 9 5/8" O.D. 0 _ 10257' 8 1/2" 102_57 ' 13800' TOTAL DEPTH CSG. SIZE FROM TO HOLE SIZE FROM TO 13800' 7" O.D. 9746' 13782' 8 1/2" 10257' 13800' _ -- DATE TD REACHED CSG. SIZE FROM TO HOLE SIZE FROM TO 6-9-?8 O.D. _ -- TOTAL DAYS CSG. SIZE FROM TO HOLE SIZE FROM TO 36 O.D. _ -- BITS: NUMBER AND SIZE 30 - 8 1/2" MUD UP DEPTHS 10257' TYPE MUD Prehydrated Gel, Drispac COMMENTS Built prehydrated gel and filtered inlet water system to mill section in 9 5/8" casing. Cemented of£ old hole and started drilling new hole at 10257'. Built mud system with prehydrated gel - filtered inlet water - and Drispac super low £or fluid loss control. Small amounts o£ Imco VC-10, Poly-RX, and Thin were used to aid in fluid loss and theology control. Drilled 8 1/2" hole to 13,800'. Ran 7" liner from 9746' to 13,800' and cement test resqueeze liner. T. Shambo, McKenzie IMCO REPRESENTATIVE IMCO FORM 509 ORM ~J355 ~.I"o IN~I,~,A, 10M'~7-76 COST SUMMARY P.O. NUMBER TOTAL DEPTH 61"917S A Division of HALLIBURTON Company 2400 West Loop South, P.O. Box 22605 Houston, Texas 77027 A/C 713 622-5555 DATE PRODUCT ~.~ ~ :~ . . ~?,iCO C,'..~C REG DR~SPAC SL ~-,iCO.POLy RX I ~ICO XC TE~f,,iCAL SERV UNITS :9 ,i 8O 3O 60 ?0 20 O0 15 ~0 '5 ~3 ., .,00 . O0 SIZE ~OOL~ 1001.8 i, OOL~ lOObB 50L~ 50L~ ~vL~ 50L9 lOOL5 5gAL AMOUNT 37. 5:0 0 8~20j00 67~0i00 3360'¢0 zs ooioo 16360[00 l Si sioo ,, . I MCO REPRESENTATIVE, ., TYPE MUD Ib CO SERVICES A Division of HALLIBURTON Company 2400 West Loop South, F~ 0 Box 22605, Houston, Texas 77027 A/C 713 671-4800 Mc Kenz i_e_~_h ambo Gel, Wa~er RECORD OF DRILLING MUD TESTS CASING 9,,.,,,,5/8 c~ 10257 HOLE SIZE 8 1Z2 NO. BITS NO. DAYS 3_0 ., 3_6_ ALKALINITY COMPANY UNION OIL COMPANY WELL NAME & NO. TBUS G-12 #2 WELL FIELD COUNTY STATE Trading Bay Kena i Alaska CONTRACTOR R Parker Drlg. METHYLENE BLUE lbs/bbl 130 to cu tot visco lete Inlet ace t 900 e fi 1 80 1 bar hours for .o37o Drilling 5-21 ~0591 Drilling and[ dri~,;p i-22 ~.0660 Added pre! _~r_be.dlo : t:,l~, ' ', '~ :~',;,I,:! '~, I~ : '; ..... ,:;,:~; , :h ~ C ;:,,I ,f /!~.: ,,,t'I ~!.:',: ;,, l i~,,,d',,~,, t~, (t,,:::~,~ ', ' ' :';,~ ',",,[ iL'/'t) · '~,,,z~ ,' I:',' I~.;[,i;: I,, ,~, ~ ~[,:,;,: , I ,' ,: ,' , , , ~ ; ,,. Ii, ; for 35 cl an 2O , is- 20 d 2 20 gel, 7,5 FORtA 514 . iIVICO SERVICES A Division of HALLIBURTON Company 2400 West Loop South, IR O. Box 22605, Houston, Texas 77027 A/C 713 671-4800 IMCO REPRESENTATIVE McKenzie, Shambo TYPE MUD XC-Po lymer DEPTH fl 10997 e 11232 i out ,ing 5000 ke to sh 10260 ped bls. RECORD OF DRILLING MUD TESTS CASING HOLE SIZE NO. BITS NO. DAYS ALKALINITY JCOMPANY · __UAL[ON O_IL_COMPANY WELL NAME & NO. TBUS ~_!_._~_~.~ Page_2~.~ WELL .o. I__ I / __L_LZ~-]--I--I~E FIELD COUNTY STATE Tr_a._d__ing ~_a_y_ .... __Ke. nai_~ CONTRACTOR -~ J R _Paz'kez. Dz' METHYLENE BLU[ 11512 cula 10200' ered lled to 11794 dyna dyna 6 Lled t ill 71 121, FORM 514 [[vlC ) SERVICES A Division of HALLIBURTON Company 2400 West Loop South, R O. Box 22605, Houston, Texas 77027 A/C 713 671-4800 McKenzie, Shambo IMCO REPRESENTATIVE Gel, Drispac TYPE HUD DEPTH lt. 12155 50bb 12235 ling 12319 tool mud 12459 12602 12827 Dr 12152 13350 t 1371O led t and 13800 ed t stucl too 13800 RECORD OF DRILLING MUD TESTS CASING HOLE SIZE NO. BITS NO. DAYS ALKALINITY on COMPANY UNION OIL COMPANY WELL NAME & NO. TBUS G-12 #2 Page 3 APl WELL NO. 1____11__1___1 --F I I-Fl- I 1~-~ FIELD COUNTY STATE Trading Bay Kenai Alaska CONTRACTOR R Parker Drlg. METHYLENE BLUE Ibs/bb 20 20' g3 17~ res 3 17. 4 2O 4 20 4 22. FORM vlCO SERVICES ~~ Houston, Texas 77027 A/C 7t3 671-4800' McKenz±e, Shambo IMCO RE PR ESENTATtVE Gel, Drispac TYPE MUD DEPIH ft. est 9746 out 9746 9746 13782 13782 RECORD OF DRILLIHG MUD TESTS CASING HOLE SIZE NO. BITS NO. DAYS COMPANY UNION OIL COMPANY WELt. NAME & NC). TBUS G--12 #2 Page 4 ^P' ISTATEI co0N~/ WELL -WELL ~o. I I_I'-I__L__II I 1 COUNTY STATE F~ading Bay Kenai Alaska C~N f R A,CTO R R arKer Drlg. ALKALINITY Ibs/bbl 20 17. 13782 13782 out 13782 13782 13782 514. · Document Transmittal Union Oil Company of California unlen DATE SUBMITTED ACCOUNTING MONTH · Sept 14 ~ FROM T°State Division of 0il & G~Ls 3001 Porcupine Drive R.C. Warthen ATAnchorage, AK 99504 ~.0. Box 6247 Attention H. W. Kugler Anchorage, AK 99502 TELEPHONE NO. TRANSMITTING ThE FOLLOWING: TRADING BAY UNIT G-12RD ~/2: 1 set Sepias & Bluelines, final logsI _ L~& 2" DIL : L.U"' '- ...... 5" CN-FD ~/Directional Survey . 9~ Please acknowledge receipt by signing and returning copy of document transmi~ tal. DATE: FORM 1-2M02 (REV. 11-72) PRINTED IN U,S.A. Union Oil and Gas F~ision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union August 9, 1978 Mr, Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99510 Dear Mr. Hamilton' Transmitted for approval and information are the following duplicates of State forms that were not received 'in your office via our transmittal of July 26, 1978' Completion Report Subsequent Abandonment Sundry Notice TBS A-32 Sundry Notice TBS A-10 " " TBS A-11 " " TBS A-14 " " Sincerely yours, JinfCR. Callender Dist. Drlg. Supt. 6. ~E Dt/25IGNATION A-ND SEi~I.A-~ NO, ADL 17594 7. IF INDiA. N, A. LA_ADT~I'EF_, OR TRIBE 10. FIELD A~ND POq2>L, O11 WII-.DCAT McArthur River-Hemlock Sec. 33, T9N, R13W, S. SUBMIT IN DU~i~I.?ATE* STATE OF ALASKA ',se. other m- st ructloJ:.~ on 5. API ~'UN~ CODE reverse o~[ AND GAS CONS[RVA~ON CO~rT~ 50-] 33-20]]6-02 , , Wik[ COMP[ilION OR R[fOMP~[IION REPORT AND ~OG * 1~. TYPE OF"~VELL: oH, ~ u*s ,,'~L~ W~L ~ ~ ~ Other water inj~ b. TYP~ OF COMPLE~ON: w E L L OV ER E N ~ BACK :ESVR. O~he~ , ~. ~,~,= o~ o~=o= Trading Bay Unit Union 0il Company of California ,.w~No. ~. ~=~ o~ o~=~=o~ TBUS G-12RD-2 P. 0. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL (Report location clearly ~ in accordamce with eny State Fequ~rememt~)' · t~ Conductor ~37, Grayling Platform, Leg 2, 1874'N & 1386'W of SE cor. of Sec. 29, T9N, R13W, S.M. om~v=~ At top prod. Interval reported below I I ~3~ ~r~ 1511 W of SE cor. of Sec. 33, TgN, R13W, S.M. 12. PE~NIIT NO. 214'N & 1316'W of SE cor., of Sec. 33, TgN, R13W, S.M. 78-42 5/18/7~ 6/~/7~ 7/1/78 99' RI above ~]q RNa'MB I lq 6~.~'MB I ' 10~9q7'-lq. R0~' ~AS~NA'~N~VAL(S), O~--~IS kO~I~TION--~P, BOSOM, NDIE (5~ AND ~)' -- ........ l~. WAS DiRE~ON,~ I I ~ SURV~ ~DE Top Hemlock Bench ~4.- ]3,390 MD, 9799 TVD ~ Yes Base of Hemlock Bench ~4 - ]3,403'~D, 9807'TVD 24.TkrpE ELECTRIC .a~ND OTHER LOGS RUN FDC-CNL-GR, DIL-SP-GR, Caliper Gyro, CBL i --- ill ''25.'" CASING RECoEL1D ('l~ort all strmss set in well) CA. SLNG SIZE ' I IVEIGHT, DEPTH SET (M/)) HOLE SIZE See attachment 26, L!NEX tq,.E C O PtJ) CF_~MLNTING RECOP,.D I /~%IOUNT PULLED 27. TU BLNG RECOILD 9734' 13,770' 700 sx 28. PE!R&mORATIONS OP~ TO PRODUC'I~IO~ ~interv~, size and number) Bench #4 13,390'-13,265' 4 - .40" HPF , i iiiii ilii , i 30. Pt%ODUCTION 3 1/2" 12,941 ' 12,870' "~, ACID, SiiOT, Fi~C~ URE, Ck~',IENT SQUEEZe, ~FC. L~ ~ 9734'k~ner lap 1..200 s~ sox 13,410'-13,412'I' .50 sx sqz 13,014'-13,016"I 57 sx S~z ~2,97~'-1~,~74'1 10B sx .sqz. DATE FIRST PRODUCTION [ PRODUCTION MEI I{OD (Flowing. gas lift, pumping--size and type °f pump} [ V; ELL S:F~A'I'U S": ~.~)~:~t[J~g o r~nut-in) HOURS TESTD 'lmtoxE SIZE DATE OF T[ST. OI~BEL. G.~AiCF. W/,'I~{--BBL. GAS-OiL ILYTIO FLO%V, TUBING CASLqG P~SU~ {CAL~~ OI~BBL. 31. DISPOSITION0F GAS [Sold, u~ed for fu~l, vented, e~c.) iWA.'I~FL--HBL. 1 OIL GRAVITY-A. PI (COR.R..) I TE:ST W ITN ES-'4~D 3-9-. LIRT OF ATTACHMK;NTS 33. I hereby certify that the foregoing and attached information is complete and correct aa determined {'rom all-available records s,~-~z~~ /~-~/~_~-- --,~XT~Z ai~.t. Orlg. Supt. 7/25/78 i ii . i 11 , _ F. -, ...... ~' ~'-~ iii ii iiiii i *(S~* [retraction, d S~c¢~ lot Additional Da~o on Rcvcr~e Side) ItqSlrRUCTIONS General: This form is designed for submitting a complete and correct well completion .report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ' ments given in other spaces on this for,~ and in any items 20, and 22:: If this well is completed for separate, production' from more than one interval zone (mulliple completion), so state ~n item 20, and in ite,-~ 22 show the [.)~c:J~ci~.r.i interval, or i~te~vals, top(s), bottom(s) and name (s) (if any) for only the intervdl roi)erred in iten~ 30. Sul:')rnil a separate report (page) on this form, adecluately identified, for each addilior~al interval to be seperately produce:i, show- lng the acktitional data pertinent to such interval. Item26: "Sacks Cemenr': Attached supplemental records for lhis well should show 'the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each inlerval to be separately produced. (See instruction for items 20 and 22 above). .... 34.."';Ub, IMAII. Y ()1,' I"(~";IMA'I'i~.)N 'I'I'.Z'-:,'I',$ I'Nt"I,LII)IN(; IN'I'ICIIVAL, TF, u;'rI<D, l'llg.$.qtlHi~] DATA ANT) J1F,('()VF:I(IF2...; WAq'ICI{ AND MUF) NAM~ No drill stem tests Hemlock 12,973' 9,462' West Foreland 13,703' 10,033' ~d CC)HE DATA. A'I'I'A(.'II. IIII1EF' ID, I~]SC~I,{.[I21,'IT, IC/N.'q OF' LITIIOLOt.;,¥. I~(IF(¢).'qI'PY. FllA¢'TTJIJ. lq, S. AND 'l)l.'-'l'l.'C'~'~l-'£) .'qlI¢.).V,,'S OP ()ii.,, .(;AS :eli ~ , , , , ,,,, ,, No cores WELL COMPLETION REPORT & LOG TBUS G-12RD-2 Page 2 CASING RECORD C~sing Weight Grade Depth Hole Cement Pulled 17 3/4" .312" wall Spiral Weld 602'MD 22" 775 sx 13 3/8, 61#/ft. J-55 6,013'MD 17" 2525 sx 9 5/8" 40, 43 1/2 N-80 '12,697' 12 1/4" 2000 sx & 47#/ft. P-110 7" 29#/ft. N-80 13,709' 8 1/2" 450 sx None None None Cut & pullet from 10,386' *NOTE- Window cut in 9 5/8" from 10,257'-10,313' and original wellbore abandoned below 10,313' Eastman ~ Whipstock l ~ PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY UNION 0IL COMPANY OF CALIFORNIA COMPANY TRADING BAY UNIT C,-12 RD WELL NAME COOK ZNI~T JOB NUMBER A578 G031 ? A678 G0351 LOCATION TANGENTIAL TYPE OF SURVEY GYROSCOPIC GYROSCOPIC DATE 5-11-78 6-18-78 SURVEY BY EDWARD J. BUTLER OFFICE LINI(DN 011... [)F' CAL+ Gl2 RD :i1:2 F'LATFC)RM GRAYLING, COOK INLET KENA]: , AK. SURVEYORS BUTLFR, BEATTIE VER'T'ICAI_ SECT]:ON IS IN I::'L. ANE OF:* BOTTOM HOLE: CI...OSLJF;:E, UNI'ON OIL.. 01::' CAL.., G1'2 F(i) :it: 2: MEASURED DRIFT DRIFT DEF'TFI ANGLE DIRECTION FEET [I M D M 622. 700. 800. 900. 1000. 1 :I. O0., 12 C: 0 · .1.300,, 2.400· .'!.500. 1600,' ,1.700, .1.800. 1900, 2000, 2100, ,,,,.) .,..,.:. 00 · 2300. 2400. 2,500. 0 15 S 56 0 E 4 O' S 34 0 E 8 30 S 37 0 E 11 30 S 49 0 E 16 0 S 51 0 E 20 0 S 53. 30 E: 23 30' S 51' 0 E 27 15 S 50 0 ~..r. 31 0 CS 50 SO E 35 0 S 50 30 E '' TRUE' VERTICAL. VERTICAL R E C T A N G U L. A R C L 0 S U R E DOG LEG DEF'TH SECTION C 0 0 R D I' N A T E S I:~ISI'ANCE] DIRECTION SFVERITY FEET FEET FEET F'EEY I) M DEG/IOOFT 6°1+o6,. , -3,71 _,'? 79 N ,._,"~ '15 W 699,77 1,72. I,~'~,~. S 0,59 E 798,67 16,50 ].3+53 S 9,49 E 896+66 36,05 ':)6.61 S ')4.'::' ,,S E o5 S 45 96 FZ 992 ~9 62,87 43 · '; ~ .1. 086,76 96,08 65,24 S ..:,,), ,._ , 7'?. ,. E 1178,47 134,87 90,3,1 .."!.';].0:3,71 E 1267,37 179,60 2.19·'77. S 1'=°,_,~,, 79 IF I. 353 · 08 ":' '? 9.81 3. 5 "':' S ....... .,:.. · 53 3. 78 ,, .."53 E." 1. 4 S 5, () 0 .~ 8,.,, 7 S 3. 8 9 · 0 ,1. ::1,. ,..,.. ~,."~ ')''' · 7 9 F 2600. 2700, 2800. 2900, SO00. 38 30 S 48 0 E 3.53.3,26 42 0 S 48 0 .E 1.587.o57 46 15 S 48 0 ~ 3.656.73 50 0 S 46 30 E:'-.~ 1721,00 34.6o97 230o67 S 269.05 · ") ' r~. . . 412.7~,79',!;: :j~: ,~.7.,a., 4,1 S 31'8,77 E -, ,~ S 483,-85 ~,.~ e,~S, 78~ 372,46 E .1.841 73. 7:1.6 98 , , 85,77 'S 544,16 .1. 899,78 797, ~."{ .1. 54 .1.; ...~o;..;, c..": 603.., 70 · 1.954,97 879,92 599,74 CS 66S,18 "' ....... '"::' 6 S · ":'"' ' '::; ' ,=007· ':>9 , ,. , 79 656,7° S , .,...6. ,.. 4 2057·98 1049,04 7:1.6,64 S 788, ',:? 2 60 30 S 43 0 E 58 30 S 45 0 E 56 30 S 45 0 E 54 0 S 46 0 E 52 30 S '46 0 E 3,7:1. N 41 17 W ].,82 S 19 0 E 4,8 '"'~ S. :'55 3 E 4.":'o ].6. o,:. . 7,6.3.9 S 42 41 g 2:,.6 6S,59 S 46 1.7 E 4.=' '2107,22 21.59,47 2214.66 2273,44 2S34,32 354 · S 9 ,<:i 4 9 ,.-.. 4 I::: S, 8 '> 29 CS 4,=1., 49 '1.0IE 3, ~' 493,51. CS 49 0 E. 4,3 570,05 S 48 40 F:' 2:,9 649.09 ,5148'28 E:' 2.3 729,44 S 48 .1.5Ii:: 1,3 810.83 S 48 7 E: 1·.1. 894.3.4 ,:~47 53 ii: '2,4 c~ 79, .41 S .47 5 S !:::. '~ "::' .1.()65,53 S 47 .21.4 E '2,0 ,1. 135,69 . .*;. ,~;. x.~ · .,,~ 3.7302,96 :1. 383 ,, O0 1463..49 7130.30 S 847.88 ii: 840,59 S 908,1.7 E 899,55 S 967,14 I1'" 955,75 CS 1025,3S E: 01'0.86 CS 1082.,10 E: ]. 1,,,=.=; ~ 29 S 47 ,='"' 3 E: ,_v .8 ,.:.37,4 8 S 47 :L 3l::'.' ':' 6 ]. 32 O+ 8,1. S 47 4 I::: ,:·"" 0 1401,70 S 47 i ii:: 2,6 o 7 t::: :L, '=' 3.48:1.'.02 CS, 46 ':: .... ...,I 3100. 3200. 3300. 3400. ,..o 0 45 30 E: ,_ 1.67 57 30 S 45 0 E 2445.40 59 0 CS 46 0 ii"' ' 2496,91 57 .1. 5 S 47 0 if.". ") =: ":: ,. ,,,., 3..'01. 5 5 0 c> 2 6 08 ,. ,, 4 6 0 tE ,' ,36 1542,64 :L626,28 1711,0.9 :1.794.07 1875,12 1068,28 S :1.1.40,82: [:' :L 1"27 + 93: CS 1200,46'E' .1. 187 ,. ~:.,.., .1. ~. I::: .1.,.."> 4 4,.:::,"'.,..'-" S 1 ._,'7 '::,,.. S . 6 3 ["' 130'!. + '72 .'.':; .1. 382 · 56 E: ].562.9:L S 46 5,3 E: 2,5 t') '.. 3.64'7,z. 1 cS 46 47 Ii-" 2,5 1.732,92 S 46 4'55E: 1."',. 1.817.02 S 46 45 t.'.Z 1..9 1898,93 S 46 44 l:-Z 2·4 UNION OIL: OF CAL G1'~ o ~ RD $2 MEASURED DRIFT DRIFT r~EPTH ANGLE OIRECTION F E E T I) M I) ' M TRLJE VERTICAL DEF'I'H FEET 3600, 52 15 S 3700. 50' 303 3800, 49 30 S S900, 47 30 S -4000~ 45 SO S 47 0 E 2559,59 45 30 E '~273.3o19 47 0 E 2798,14 47 0 E 2865,70 ,.,.'* '"/ F.', ~..'. "29 .?;~ '=' , 79 4100, 4200, 4300, 4400, 4500, 45 30 S 45 ' 0 E 3005,88 46 30 S'"45 '30 E 3074,71 47 0 S 44 30 E 3142,91 47 30 S 46 0 E 3210,47 48 30 S 45 0 E ~276,74 4600, 4700, 4800, 4900, 5000, 5100, 5200, 5300, 5400, 5500, 45 0 S 41 30 E 3680,00 44 45 S 41 0 E '~751,02 44 30 S 41 0 E 3822,34 44 30 S 42 ~0 E 3893,67 44 30 S~'42 ~0 E 3964,99 5600, 5700° 5800, 5900. 6000, 44 30 44 30' 44 30 44 30 '44 30 S 42 0 E: 4036.32 S"41"30"'E 4107,64 S 41 SO E 4178,97 S 41 30 E 4250,29 S'40 0 E .... 4321..62 6100, 6200, 6300, 6400, 6500~ ._. 44 15 S 41 0 E 4393,25 44 30 S 41 0 E 4464",57 44 30 S 40 SO E 4535,90 44 30. S 40 ~0 E 4607,22 44 0 S 40 .SO E 4679.16' 15:18:04 '26'-JUN-'78 F'AGF NO, VERTICAL SECTION FEET R E C T A N G U L A R C L 0 C 0 0 I'"~ 0 I N A T E S DISTANCE ........ FEET FEET S U R E BOG LEG fIIRECI'ION SEVERITY T.I M DEG/:LOOFT 1953o13 1355,65 S 2029; 57 1409;'73''' S 2!04,60 1461,59 S 2'1.77,35 :1.5.1..1. °87 S '~'~ 47 ' 72 - 60 ,~,. lb .51 S 1440,38 E ].495,42"E ].551,03 E ].604,95 E c,...~/,1':~ E 1978,00 'S 46 44 E 2,9 -2055, .1.4 S 46 41 E 2,:1. · .131,18 S 46 42 E 1,5 ,.'~204,9.1. .... S 46 43 E "'~ 0 .,% , 2,., ''~ 76,23 S -:::. 6 ~.t-'.!!: i;:; 2. .... 2318,46 1610,95 S 2390, 32 " 1661,79 S 2462,93 1713,95 S "~=:'~'-: 87 1765,17 S 2610', 15 1818, .1. S S 1707,55 E 1759,29'E' 1810,55 E 1863,59 E 1916,55 E 2347,53 S 46 40 E 1,4 "2420;'05 S 46 S8 E 1ol 2493,14 S 46 S4.E 0.9 2566,86 S 46 SS E 1,2 2641.73 S 46 S1' E 1,"~ 29 , S051,06 :.~ 12.1:, 35 3191.32 S261o16 20~0,29 .S 2083 :, 7,4 ,,S 73330, ? ? ,...34,.,, 6<2 S ].969,64 [,' 27.17.44 S 46 27 E 0.8 2023.68 E 2793o19 S 46 26 IE 0.8 2077o51 E 2].2.9~6'4 E:' .2942.36 S 46 22 E ].,5 2179..11 E ~014.77 S '46 t7 E: 1.8 · ") .~ ,") I::.' ,-.. ~-, ~,,.~, 97 E S 085,24 ..) 46 ,1. 1E: .1., [3 2272.3.5 I:Z '3155',~-~;6.' S '46 4 E 0.4 2318o14 E 3225o18 S 45 57 t.Z 0.2 2365,49 E 3295,.1.5 S 45 53 E ].~1 2412,84 E'" 3365.12 S 45',19 1!!: 0.0 3400,88 2397,77 S 3470.°~ ....... ~n ~'~ S 3540.75 2502.76 S 36].0.68 2555.26 S 3680'.71 ...... 2608,95 S · '), ":; c , 74 S · , *,,, ? E 3435,06 45 44 t::.' O, 4 '2506,i9"'E' S504"97 .... S .45 .39 E:' .... 0'4 2.':J.;52,63 [.- ;3574,88 E.;45' 34 iii: 0,0 :~599 07 ['" 3644,79 S 45 "~ .... ~,. 9. E 0,0 2644,13"E: ....... 3'7.1.'4,57 'S 45 ,.~"~3 E .1.,.1. 5750.37 266]..61S S820,34 2714.51S 3890.34 2767.8:1. S 3960,35 2821,:1.1S 4029',73 2873,93 S 2689.91 [:' 3784.15 S 45 18 I:Z 0.7 ,..')735,89'E 3854,05 S 45 :L3 E 0,,., ''~' '2781.41 EE 3923,90 S 45 8 E 0,4 2826,93 E 3993,'77 S 4'5 4 IE (),0 "~qT"~ ' =' ' ...... )"~ ' ' ........ IE . UNION OIL OF CAL, G12 RD ~2 MEASURED DEF'TH FEE]' .... ' .......................... TRUE ..... DRIFT DRIFT VERTICAL ANGLE DIRECTION DEF'TH D ..... M ........ D M .... FEET' 15~18;04 26--.JUN--78 . , / . VERTICAL R E C T A N G U L A R C L 0 S U R E SECTION C 0 0 R D I N A T E S DISTANCE DIRECTION FEET .............. FEE1 FEET II M. F'AGE NO. DOG LEG SEVER]:TY' DEG/100FT 6600. 6700. 6800. 6900. 7000. 43 45 S 40 30 E 4751.39 43 .... O' S 40: 30 E ' 4824.53 42. 0 S 40 30 E 4898.'84 41 .30 S 40 30 E 4973.74 42'"0 S 40 "O'E 5048*05 4098,79 ~:~.~,51S 916.96 E 4131,96 S 44 54 E '4166,91 2978~S?'S" 2961.25 E 4199~963 44 50 E 4233.74 3029.25 S 3004.70 E 4266,69 S 44 46 E 4299.92 3079.64 S 3047,74 E 4332.77 S 44 42 E 4366.77 S130.90' S 3090.75 E- 4399.46 'S 44 38 E 0.7 _l.0 0.5 0.6 7100. 7200. 7300. 7400. 7500, 43 0 S S7 30 E 5121.19 4434.97 3185.01S 3132.27 E 4467.14 S 44 31E 43 45 S 38 0 El 5193.42 4504.12 3239.50 S 3174.84 E 4535.85 S 44 25 E 44 30 S 38 0 El 5264.75 4574.21 3'294.73 S 3217.99 E 4605.5]. S 44 20 E 44 15 S 36 0 E 5336.38 4643.96 3351.18 S 3259.01E 4674.56 S 44 12 E 45 0 ~ 32 0 E 5407f09 4714.33 3411.15 ~ 3296f'48 E . 4743.70 S '44 I E 2,0 .1.,4 2,9 7600. 7700. 7800, 7900, 8000~ 45 0 S 34 ,'0 E; 5477;80 ', 47~4,90 3469,77~ ~' S 33:36.02. E 48:i.S,35 S. 43 52 E: zo s ?'0 E s E: 44 0 S S5 ~l:'O ;K 5622.27 A923.10 3582.36 S 3416::,32 E 4950,21 S 43 38' Il 43 0 S S5 ~:'0 '5695.41 49.9::L',.~22 :$6~8.,~3 8'.,'.'.3455~.44 E 50:[7 65 S 43 31 E ,12 30 S $5 30 .,. ~'~.:57~9.~'1'4 5058 74. ~,69,~2S S 3494~.67 E 5084 ,:,.., ......... , . . 8100. .41 0 8200. '42 45' 8300. 43 0 8400, 43 0 8500. 43'-30 S 31 30 E 5844.61 5].23.97 S749o1'7':S 3528;95 E:- 5148,76 S 43 :[6 E S '26 "'0 E 5918,'04 5190.45 S81().18 'S S558~71"E 5213.'62 S 43 3 E S 26 0 E 5991.17 5257-.25 7871.47 S 3588.61E 5278.86 S 42 50 Iii: S 23 0 E 6064.31 5323.23 3934.25 S 3615.25 E 5343.07 S 42 S5 E S"22 .....0 E .... 61'36~85 5389,52 3998.08'"S 364I".'04'E 5407~57' 'S 42 19. E 8600, 43 30 S 22 0 E 8700° 4~ SO' $ 21 O'E' 880~', 43 0 S 20 0 E 8900. 43 15 S 20 0 E 9000. '43 30 .... $'20 ..... 0 E' 6209, ~8 =: ,...455,8.l 406],,90 S 3666,83 E 5472,17 S 42 4 6281.9 '~ '~ ~'='" 46 S 41 49 E ,~ 55~1.76 41.26;].6 S 369I~49 E c:' ~' ~ 6355 06 .~.6.75 4190 25 . . ~) 3714.82 E 5599.83 ,:)4]. S4 E 6427.89 5652.05 4254.64 S 3738.25 E: 5663.61 S 41 18 E: 65 00.43 571'7 64 4'319 .... '~ ' . .S."S "37'61~80 E ....... 5'727~80 .... S '41 :~ E 2.0 0.9 1'. 0 ()~ 6 S, ]. 4,1 0,2 2,0 O, 8 0.0 0.7 0,8 0.3 0.2 9100. 9200. 9300. 9400, 9500. 43 0 S 19 0 E 6573.57 5782.27 41"30 S 18 0 E6648,'46 5844~67 .... 41 0 S 16 0 'EE ' 6723°93. 5905,.65 41 0 S 16 30 E 6799'.41 5966,84 41 0 8 14"30 E 6874'88 6027"]:7~ 4383,80 S 3784o00 E-" 579:1.,06 S 40 48 I'Z .4446,82 S 3804~48"'E ..... ":5852',20 S 40 S3 EE 4509,89 S S822.56 E 59:1.1.94 S 40 17 E 4572.79 S ~841'19 E 5972.03 S 40 2 E 4636.31 S 3857~62: E ' 6031.30 S S9 46 E 0.8 1.6 1.4 1.3 UNION OIL OF CAL. Gl2 15;18;04 26-JUN-78 PAGE NO.' ................. · TRUE MEASURED BRIFT DRIFT VERTICAL VERTICAL R E C T A N G U L A R C L 0 S U R E DOG LEG [EFTH~ ' ANGLE DIRECTION DEPTH SECTION C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D" M D M FEET ' FEET ............. FEET FEET Ii M DEG/IOOFT 9600. 40 30 S 12 0 E 6950,92 6085.72 4699,83 S 3871.12 E 6088,85 S 39 29 E 9700. - 40 0 S 12 O'E 7027.52' 6145;67~ 4762;71 S 3884~49 E "&145.94 S 3~ 12 IS 9800. 40 0 S 12 0 E 7104.13 6201.62 4825.58 S 3897.85 E 6203.18 S 38 56 E 9900. 43 SO S 12 0 E 7].76.'66 '6263.67 4892,91S 3912.16 E 6264,63 S 38 39 E 10000. 47" 0 "'S 12 0 E" 7244.86 '6329,"61 4964,45 S '392'7,37 E 6330,09 S S8 21E ' 1.7 0.5 0.0 3.5 5.5 10100. 46 .45 S 14 0 E 7313.38 10200. 45"45 $'14 O' E 7583.16 6396.33 5035.12 S S944,99 E 6396,52 S 38 5 E 6461~.95 5104063 S 3962°32 E" 6461.98 S 37 49 IS 1~5 50 FT. STATIONS IN BUILD UF' ZONE _ . 10250, 44 45 S iS 0 E 74 i. 8 · 6'7 50 FT. STATIONS IN'BUILD LJ~ ZONE 10300 '43 30 S 16 %0 E> 74.54 94 10350, '44 0 S 1~ c~,g.,L~),.L:;,.74~O.~ 90::i.~ 10400. 44 45 S 23 0 E 7526.41 10450. 44 45 S 21 0 E 7561,92 10500. 45 SO S 2.1 '0 E 7596,97 10550. 45 0 S 21 0 E 7632.32 10600. 44 30 S 25 0 EE 7667.99 10700. 45 0 S 32 0 E 7738.70 10800. 45 15 S 27 0 E 7809,10 10900, 44 0 S 24 0 E 788].,03 11000. 43 45 S 26 0 E 7953.27 11100. 42 ....... 0 S SS 0 E" 8027~58 _ 6493,74' 5138.92 "' o 3970.24 E 6493..95 S 37 41 E ~;~ ~i? "~ ' ' ..... "' 9'"' ~ ..", ~ S 397.,:.~ E '65~5,94 37 35 E ~ o 9 E 6592.96 .~ 37 24 E '6626,63 5'~ ' o ~.70.].1 S 4017.40 E" 6626.74 o S7 19 E 6660.80 5303.41 S 4030.18 E 6660.97 S 37 14 E 6694.67 5336.42 S 4042.85 E 6694.92 S S7 9 E "")q ~- S 37' E 67~;87 .... 5~68.18 S '40,~7.6'6'"E ................ 672~'."1~ 5 6799.24 6869~03 6936.54 7004.27 7070:,'96 5428.14 S 4095.13 E 6799.62 S 37 2 E 5491.42 S 4127.57 E 6869,57 'S 36 56 E' 5554.88 S 4].55.63 EE 6937.29 S 36 48 E 5617.03 S 4185.94 E 7005.25 S 36 42 El 5673.15 S 4222.5'9 E '7072,00 S' 36 40 E 4.9 5,8 2.8 ].. ~::: i ,0 5.7 5.0 3.6 2.4 1.4 11200, 39 SO S $9 0 iii: 8104.75 7134,55 5722.59 S 4262,42 E 71¥5~56 S 36 41E 11500, 59 0 S 36 0 E 8182,46 .... 7197,46 5773,50 S 4299,41E 7'198.48 S 36 40 E 11400. 39 0 S 55 0 E 8260.17 7260,19 5826,28 S 4353.68 E 7261,29 S 56 39 E 11500, 39 0 S 53 0 E 8337.89 7322.91 5879,'06 S 4367.9'6 E 7324,09 S 36 37 E 11600, 40 t5 ' S 32 0 E'I 8414,21 7'387.2'1 5933,85' S' 4402,20 E 7388,50 S 36'3'4 E 2.0 1.9 1.4 JNION OIL OF CAL0 Gi2 RD ~.2 . , 15;18.~04 26-JUN-78 PAGE NO T R U E - ....................................... : ........................................ :~ MEASURED .DRIFT DRIFT VERTICAL VERTICAL. R E C T A N G U L A R C L 0 S U R E DOG LEG DEPTH ANGLE DIRECTION DEPTH SECTION C 0 0 R D I N A T E 'S DISTANCE DIRECTION c ....... . o E V E K I T l FEET D ...... M ...................... D ~M FEET FEET ....................................... PEET ................... FEEl ..... D M [E.G/100FT 11700. 4:1. 45 S S2 0 E 8488.82 7457,.48 5990,{~2 S 4437°48 E 7454.88 S S6 S2 E :1.,5 11800, 41 45 S S4 0 ~ ....... ~'=~'"~ 42 ""=' o ':z~. SO E: 1 S ~:. o.,,.,..,, x~19'*'95 ".' 6045T53"'"S 4474~72 E 7521,40 ~ ,~ · · . . "~ ~' P =' , .." S '2 1:t. 900 4:1. 0 S 34 0 E 8638 89 /~,.:)~,.40 6099 92 S 451:[.,41 E 7586,95 36 9 E 0,7 12000, 41 4~ S 34 0 E: 87:1.3,50 76S1,86 6155~12 S 4548,64 E 765S,47 S 36 28 E 0.7 , -' o ...... S 'S 2 12100 40 45 S S2 0 E 87,.~.26 7716'+82 621'0"~'48 S 4583~25'E: 7718+55 6 6 E 1~7 :t ''~ ~ ..... ,.. ~'.. 00 +$ 9 0 b S 6 0 E: · 13866.97 12S00~ 39 15 S 40" 0 E: 8944,41 1":400.~ 39 45 oe 39' 0 E o021,"~9,,... ].'>,~(,. O, 41 0 S 42 0 t:: 9096,77 12600. 41 30 S 47 0 E 9171.66 7779 · 72 626:1. 0 S 9 S 46.. ,.. '"~ 0 .2 ~..'? E "":"~"~, ~.~-~,.., 94 6S09,1:/6 S 46A0,89 E 7906,87 "~:'c 55 S 6e,,.,?,~ 4701,13 E 7972,28 6408,'3:1. S 4745.03 E: 8037',66 .......... 6'453,50 S 4793,49 E: 7781,48 S S6 25 I::: 3.1 7844,63 S ~,6 27 I::: 2,5 7908,51 S 36 28 E 0.8 7973.81 S 36 31 E ~:.°,,~"" 8038,98 S ~6 36 E 3,3 :J.':)700. 4:1. 15 S 52 9,,.46,84 12800. 40 45 S 50 O".E' 9322.60 12900. S9 0 S 49 :,O,.:'E: 9400.32 12973. 39 0 S 49. ::::,:0:: ~.,>, 9457,05 ..-973 ]:S TOF:' HEML. OCt'< 8102,57 S 36 44 E: S.S 8166.11 S' Z6 50 E 1,4 8227',64 S 36 56 E: 1.9 8272.57 S 37 0 E: 0.0 . 13000, 38 SO S 48 0 E 9478.18 8288.57 68.1.8.7'-~,.. 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C 1_. 0 S U RI::' -.' i) ]: R F C T ]: (3 DISTANCE S 37 I)I:-:GS 38 MI:NS.,:~"'° ," r." r' <"<:> r .. .:., 8786.86 F'EET UNION, OIL OF G-i2-RD 2 TRADIN$ BAY ALASKA CALIFORNIA UNIT .. PA'GE 1 APRIL 15e 1978 SURVEY DATE V~. TI ~E SECTION-'CO~FUTED--ALONG--C1ZO'SURE--- ERRY-SUN WELL SURV*._YING SR ........ ' ....... *- RECORD OF SUR:VEY MEARURED DEPTH TRUE VERTICAL SUB-SEA OEP TH D ER TH O. O,O0 I00, lO0,OO 1,00 200. 200.00 101.00 INCLINATION DIRECTION DOG-LEG RECTANGULAR S[VER ITY VERTICAL COORDINATES ~ D E G--M I-N ............ D EG-M I N D EG/'I-O-O---" SE CTION . _ ORIGIN AT KELLY BUSHING O,O0 N O.OO P'" 0 ....... 20 ............... S ........ 1 ,¢0'-? ..... ~;O'O '-~T .................;-58- S .71--~ 0 20 S lq.70 W .09 .82 1.14 S .13 W 300..' 299.99 200.99 400, 399.99 300,99 500. 499.99 400,95 0 29 -S 36-;'2-6-'17 ;2'1. O 15 S z~5.95 V .24 0 15 S 56.49 W .05.'. I-;0'~' -' I' ;, 82- S. ;63--W 1.0~ 2.1-~. S .95 1,05 2,37 S 1,33. GO0, 599.98 500.98 700. 69'9,72 600,72 800, 798.60 699.G0 900. 896,52 797.52 1000. 992.56--89 3;56 1100. 1086,53 987.53 1200, 1178,30 !079,30 1300. 1267,07 1168,07 lqO0, 1352,53 1253,53 O 50 S 57.2z~ E 4 10 S 30.29 E 8--3§ ..............S-'-39 11 42 S 51.61 E 3.79 ........ l'G-'lO ........... S 52,43 E 20 D S 51. 0 E 3.86 27 25 S 55. 0 £ 4.35 31 17 S 51. O:.:,E 2.43 3.16 S .09 W 9.63 9.~3 S 3.5g E --2~';'55 '2g-g99~S- . I~;O2'--E '" q4.27 33.58 ? 1 . 25 .... 5 P .5 6 194.59 72,08 187.q0 123.58 $. 238.03 .156.18 .S 2R.91 E 77.56 E 18~.B2 E 1500. lq34.36 1335.36 35 5 1600, 1512,58 lq13.58 38 32 1700. 158~.99 S487.9g 41 55 1800, 1656.qG 1557,46 46 0 1900, 1721.14 1622.14 ~ 9--*-2 2000. 1782,82 1683.82- 51. 55 2100, 18z~2,89 1743.89 53 5 2~00.. 1901.2q 1802,2~ 54 18 2300, 1957,16 1858,16 56 0 S ,.5.;~, 0 E 3.80 s..;¢', o F_ .5o s 5'o. o E S--49 .----0 E S ~9. 0 E 2.22 S 4-8-~--0--'E 1. ~ 1 S ~8, 0 E 1.22 S 48. O E 1,70 294.06 192.35 S 355.03 232.40 S '~20.--~0--'- - 2 7~T3-4 S .491.05 322,53 S1 56%-95 ' 372-.57 S 643.25 q2q.21 S 231.19 E 278.91 E 384.38 E 591.3~ E 722",'82 '477.10 S 56'0-;75 - :. 802,02 532.0~ S 621.18 E . 883.7~ 587.52 S 682,71 E UNION OIL OF 6-12-RD 2 TRADINS BAY ALASKA CALIFORNIA UNIT PAGE APRIL 15,~ 197'8 SURVEY DATE V ER'T I C-]:[-""SE CTI ON'-C'O ~, P UTED-'-A[:'ON'B-' CL'OSUR=~_ S P ER RY--~'~ U'N .... ~Z'E[L-'-'S UR VEY I NG--C OM RECORD OF SURVEY SU3'=I'G25'8 TRUE INCLINATION MEARURED VERTICAL SUB-SEA DEPTH DEPTH DEPTH DEG MIN 2~00. 201D.77 1911.77 57 35 2500. 2062.72 1963.72 58 ~2 2SO§. 2113.22 201~.22 59 ~O DIRECTION DDG-LEG SEVERITY VERTICAL D E'G--'M"-~'N .... D-E GT-~'~---SECTI ON, ' S 48. 0 E- 1.58 966.87 S-4'8'~,--0'-E ...... 1-~ 1-2' 'I" O 5 r', 05 s ~8. 0 E .97 1136.09 RECTANGULAR COORDINATES G~.O0 S 745.~5 m 758.93 S 873.09 E 2700. ,' 216G.G6 20&7.6S 2800. 2222.8~ 212~.8~ 2~00- 2282.~2 2185.~2 2.06 1.~00.60 869.76 2.52 ..... 1~79.55 922.50 3000. 2343.71 22~qo71 3100. 2~02.01 2303.01 3200. 2~5G.35 2357.35 3300. 2509.10 2~10.10 --3400. 2564.29 -24G5-~-29 3500. 2G21.91 2522.91 52 8 S 48. 0 E 1.58 I457.32 975.32 S 11!7.G7 E c~q 20 S 48,. 0 ~' Pe2[i 1537e3~ lO"a ..... ~_.,-68 S 1178.05 E 57 5 S--~8'; ..... O-E ...... 2;75- ..... 1~620';'07 ........ 10 85;8~--~ ..... 58 10 S qg. O E ].08 !703.77 1142.7~ S 1303.57 E "' 56 ..... 30 ............ S-~8-g'-O E ...... ~'67 .... 1785.9~-- ~ !lBg.SU- S 5~ ~9 S ~a. 0 =_ l.G8 1~66.~5 1253.19 S ~26.27 E 3600. 2683.36 258~.3& 3700. 27~7.22 2G48 3800. 2812.71 2715.7! 13 0'G-,'99-'%-'--------/:q'8 ~-~ .qT-E~ 1359.~8 S 1540.25 ) - 1. q11.97. S 159q. G1 ~. 3900. 2880.51 2781.51 ~000. 2950.91 2851.91 4100o 3021o15 2922.15 4200. 3090.28 2991.28 ~300. 3158.37 3059.57 ~DO. 322G.0~ 3127.0~- 47 19 S ~,G. O E 1.77 2169.11 ~5 15 S 45. 9 E- 2.1~ 2238.62 45 23 S 45. 0 E .I3 46 1G S 46. O E 1.14 47 5 S 46. 0 E .8-2 47 25 S 4G. 0 E .33 1463.0~ S 1GqT.~9 E 1513.25 S 1697.71 E --'15 6-5%59- .S 2380.87 1613.78 S 1~-0~.02 E ... '2-45-3.--4:1 1-G-6~.---~ 5S; .... 2526.35 1715.86 S 1905.67 E 4500, 3292.&2 3193.62 qGO0. 3358.25 3259.23 4700. 3423.62 3324.62 48 15 S 46. O E 49 0 S 45. 0 E 1.0G ~9 10 S 45' 0 5 .17 .. 2675.18 1820.-99 S 2012.70 E " ..~ 2750.50 1874.~9 S 2066.20 E U!,~ION OIL OF CALIFORNIA --6 -12-RD-..2 TRADING BAY UNIT ALASKA PAGE 3 A~.~IL._I.5.~ ......1978 SURVEY DATE VERTICAL SECTION COMPUTED ALONG CLOSURE SPERRY-SUN WELL SURVEYING CO~PANY SU3-16268 r RECORD. 0E__SUt~.VEY TRUE INCLINATION DIRECTION DOG-LEG ..... M E A R U R E CE .-. V. gRT I..Ci L---SU B -,SEA ........ _S E ¥ ER_I.Z ~[_ V E.ET_I_~ L DEPTH DEPTH DEPTH DEG MIN DEG MI'N DEGtlOO SECTION ~900. ~557.57 5~58.~7 47 25 S ~. O E 1.22 2~98.20 5~00. 3626.31 5527.31 ~6 25 S ~5. 0 E 1.2~ 297~.38 RECTANGULAR COORDINATES 1928.48 S 2118.33 19~,1,A4 S 2169.48 E 2,934.42 S 221B.88 E 5100." 3696.8q 3597.84 45 9 S 42. 0 E 1.46 52D0. 3768.16 3669.1G 44 30 S 41. O E .96 ...... 55 O.O. ...... 5839, 85- .~_l.40 -85 ..... .4~._.1,2 ................ S_._gl~. _iD_Er .30 5400. 5911.28 3812.28 5500°-5982.83 -3883.83 5600. 4054.~6 5955o~G 570D.__ 5900. 41.26,0,9 -~02.7.09 ..... g197.62 ~r,0'98 oG2 4269.15 4170.15 3041.11 3111.12 3180.75 20A7.11 S 2266.$2 E 2140.01 S 2312.30 E 2192.62 S 2358.D4 E 2403.96 E 245C .71 E · 02 S 2496.48 E .68., S 25A2.2G E 2588.11 E 2633.96 E GDO0. 4340.78 42~1.78 44 15 GlOO. 4~12,55 4313.55 aq. 8 6200. ..... z~Sz~.!2 ..... ~$85,12 ............. ~A IB G3DO. 4555.5~ 4~+56.54 A4 25 6500. 4699.11 ~600.11 ~3 46 6, 60 0 o . ~L7.7_1_.5 4 _~672_..5.*} _~- 3_35 6700. 4844.c;8 ~.7 A-5.98 ~-2 45 6800. A, 919.00 4820.00- ~2 15 S ql. 0 E °08 3GG~.02 2560.83 S 2679.74 F S 42. O E o71 3738.49 2612.58 S 2726.33 E S 42.._~LE -.1'7 3808,17 266q.°~8 S 2773.06 E .12 3878°00 2716.49 S 2819.90 E ,_7_0 3B~7.98 2769,37 S 2865.87 E °72 ~17°D7 2821.58 S 2911.25 E ~.1. (LE. ._18 4085.92 2873.61 S 295G.~8 E 41. 0 E .83 4353.72 -,o 42. 0 E .84 4220.80 297q'.80 S 3046.00 E 6}OO. 4993.80 4894.80 ~1 35 7000. 5068.01 q969.01 A2 5 710 0_. 5141.5 G fiO_~ 2 .. 5 G _~ 2,____3_9_ S ~O. 0 E 1.49 4287.14 3025.65 S 3088.66 E S 39,, O E .8~ q. 354.15 3C77.'73 S 3130.84 E ~_~9_._k~_ E .57 4421.90 ~150.39 $ 3173.~8. E U~ION OIL OF CALIFORNIA ........ 6 -.-1.2 TRADIN,S BAY UNIT ALASKA PAGE 4 _ A?_BI L_I._5_~ ] 9 78 SU R V E Y D A T E ....~..TICAL SECTION COMPUTED ALONG CLOSURE SPERRY-SUN ~IELL SURVEYING CONPAN¥ .R E C OR D.... OF=_ $ UR.V EY ., SU5-16268 TRUE ..... M EAR UR EDV ER T-ICAL--Su8 -S DEPTH DEPTH DEPTH ............ 72 00. .... 5214~o30 __5115.50 7300. 5286.11 5187.11 7400. 5355.17 525.9.17 INCLINATION DIRECTION DOG-LEG _SEVERilY _VE.~.IICAL DEG MIN DEG MIN DEG/1OO SECTION . ~ 6 S 36. 0 E 1.03 4560.05 ~3 5~ S 36. 0 E' =2D 4629.3~ RECTANGULAR COORDINATES 3185.19 s 52Iqo78 52~+1.49 S 32 55.68 E 3297.59 S 3296.~* E 7500. 5~29.6D 5350.60 76~0. 5500,,7~ 5~01..7~ 7700 o .... 5,5-75.22~- 5-~7~o22 ..... 4~ 25 S 35. 0 E .87 ~699.22 4~. 39 S 55. 0 E °23 4769.40 335~.92 S - 3336.58 E 3~12.~9 S 3376.89 ~¢+6P..93 S 3416.~1 7800. 7900, ..... 81~0° ...... 8200. 8300. 56~5o15 5546.15 44 0 S 36~ 0 E 5718..21_ .... 5619.21 __~3___~ .................. S 3 r 5792.38 56~3.38 A2. 7 S 3A. 0 E 5867..7g. 5768.78 ........ ~1 __~ ........... S 31. .... 0 E__: , 59~1.6~ 58~2.60 A2 25 S 25. 0 E 601~.86 5915.86 q2 5~ S 2~. 0 E °83 4~07.61 ___1._16__ 4975 3525.13 $ 3457.2~ E ~5~I.06 S 3496.41 E 1.17 50~2,68 36 36.66 S 3533.91 E 2.25 4.22 .83 5107.87 3692.97 S 3567.7q E 5173,55 375~.10 S '3596.25 E 5239.57 38:16.29 S 3623.9~ E BOO0. 8550. 8600. 6087.81 5988.81 6160.45 6061.45 6252°R./-- .....6153.87 87GO. 6305,63 6206.63 BBOO. 63_~8~_~_~ 6279.~6 ~3 9 S 26. 0 E 1.39 ~3 25 S 26. 0 E .27 z~3_ 36 ............ S... 22._0 E _2.17_6 ._ ~3 19 S 22. O E .28 Zt3 15 S 20. O E 1.37 53r36,~3 5373,62 ~3~.87 5505.77 ':579.89 3877.76 S. ~653 39:39.53 S 3~8A 4-903.q7 ' S 370.0... · 92 F · 05 E · 88 E ~067.08 S 4131.47 S 3735 °58 E 375g .0I E 890D. 6451.12 6352.12 43 2A S 20. 0 E .15 ____gOO_~, 6~23.76 6~2~.76 ~3 25 S 19. O E .69 :636.18., 5701.11 419G =03 S 426i .02 $ 3782.51 E:' - 9100. 6597.11 6498.11 q2 ~9 S 18. 0 E .91 9200. 6671.91 6572.91- 41 35 S i8. 0 E 1.23 576~..93 5827.2~ 4325.66 S z~3RS.78 S 38 25. ~9--E - ~ 3846,~O E 9300. 67~7.59 66A8.59 ~0 49 S 17. 0 E !.Gl 9400. 6823.29 672~.29 ~0 48 S 16. 0 E .65 9500, 6899,03 GSO0.O~ ~0 ~-6 S 15, O E .65 5888.21 5948.7~ 6008°78 4q51.29 S ~514.10 S 4577.17 S 38 6 3883.52 3900 UNION OIL OF CALIFORNIA TRADING BAY UNIT ALASKA vERTICAL PAGE 5 APRIL 15, 1978 SURVEY gATE sEC TI-oN'--Co~ P U-T E'D---A['b N SPERRY-SUN WELL SURVEYING COMPANY SU3-16268 RECORD OF SURVEY TRUE ___MEARUR ED ..... _V ER TI.C A_L ~_ S,UB_-_SEA DEPTH DEPTH DEPTH 9600. 6_~_6_,_01__6877 · 01 9700. 7052°93 6953°93 9800. 7129.63 7030.63 INCLINATION DIRECTION DOG-LEG SEVERITY VERTICAL ~,ECTANGULAR COORDINATES DEG MIN DEG MIN ~9 q.a s 15. D E 39 ~3 S 1~. O E 3~ 55 S 13. O E- SECT ION 1.10 GOG7.~8 qG38.83 S .Gq 6125.80 4700.83 S .67 6183-89 q763.35 S 39a, 6.8~ E 9900. '- 7202.A'~ 7103.~8 10009. 7270.79 7171.79 ....... 101 O D. L 7_~_3_8_._~9 7_2_3. 9.8 ~ 4-3 14- $ la. 0 E 4. G 55 S 1~. 0 E 4-7 9 S 14-. 0 E 3.3g 624-6.4-0 q829.81 S 3.68 6313.05 490,.0.68 S .23 6379.95 4,971.82 S. 3981.08 3778' 2 10200. 7408.78 7309.78 q. 5 35 S 13, 0 E 10_300. 748.0.q1__7381.4,1 4-4- 15 S 13. 0 5 10350o 7516.q9 74-17,4-9 Zt-3 ~9 S 12. O E TH[ C~LCULATICN PROCEDURES ARE BAS~-D ON THE USE 1.73 6Aa,-~ ,62 5'0-'4-1.4-I $ 1.33 6507.79 51rjg.A.O S 1.6 4- 653 ~. 87 .... 5-1-~3~2-6--~'-- OF THE TANGENTIAL OR CHOF, D 401~+. 88 E ~+ 03 T~ 78'-T_r----- ....... HOR IZ ONTA L__DISRLACE MENT = 6538.87 FEET AT SOUTH 38 DEC--. 8 ?~I,R. EAST(TRUE) Form 10-403 REV. 1-10-73 Submit "Intentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-133-20116-02 6. LEASE DESIGNATION ANO SERIAL NO. ADL 1 7594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL g.-J OTHER Water injector 2. NAME OF OPERATOR 8. UNt.T~ FAR_NOR LEASE NAME Union 0il Company of California " Tradln9 pay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 6247, Anchorage, AK 99502 TBUS G-12RD-2 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT McArthur River Field-Hemlock At surface Grayling Platform Leg #2, Conductor #37, 1874,N &1386'W of SE corner of Sec. 29, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99'RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, R13W, S.M. 12. PERMIT NO. 78-42 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of muttlpte completion on Well ComDletlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent cletails, and give pertinent dates, including estimated date of starting any proposed work. The 3 1/2" tbg. was pulled. The Hemlock perforations from 12,902' to 13,356' were squeezed with 250 sx. Cl "G" cement and 50' of cement was left on top of the retainer. The 7" was recovered from 10,386'. The 9 5/8" casing was perforated with 4 - 1/2" HPF @10,370'. 250 sx of C1 "G" cement was squeezed thru the cement retainer @10,345', across the 7" stub and out Perforations @10,370'. A window was cut in the 9 5/8" csg. from 10,257' to 10,313'. A 250 linear feet cement plug was spotted across the window. The plug was dressed off from 10,081' to 10,262'. The well was redrilled from 10,262' to 13,800'TD. 16. I hereby certify that the foregoing is true and correct · ,! / T I T.J,. ~.;, 5i,~t' Drl g. SIGNED ',~'m Ca 1 iender ~:.~,, ,/.~×,. Z--/'.~; ,/~/~2 (This s~ce for State office u~) /~ / / Supt. DATE 7/18/78 APPROVED BY CONDITIONS OF APPROVAL, IF ANY.- TITLE DATE See Instructions On Reverse Side Form No. R~V. Yl-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1o 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR P. 0. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL Grayling Platform Conductor 37, Leg 2, 1874'N & 1386'W of SE corner of Sec. 29, T9N, R13W, S.M. 5. AP! NUMERICAL CODE 50-133-20116-02 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 : 7. IF INDIAN-ALOi"! EE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unitl 9. WELL NO. i TBUS G-12RD-2 ~ 10. FIELD AND POOL, OR WILDCAT McArthur River F~eid 11. SEC. T.R.M.(BOTTOMHOLE ~ OBJECTIVE) i i [i. ' ('- ~ Sec. 33, T9N, R13W, S.M. ,'~ 12. PERMIT NO. 78-42 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED ttOLE AND ANY OTItER SIGNIFICANT CItANGES IN HOLE CONDITIONS. 28 6/1/78 12,227'TD Footage 80' 9 5/8" window 10,257'- 10,313' Completed TIH w/ Bit #20 on BHA #14. CO i~o bottom 12,132'- 12,147'. RU Eastman D.O.T. steering tool on Dialog W.L. & oriented DD run #6 to 850 left from high side?of hole DD 8 1/2" hole 12,147'-12,227' (80' in 10 hrs) D.O.T. tool failed @12,227' Pooh w/ DD (encountered excess drag @12,000'. Brok~ circ @12,000' & reamed hole). LD DD & PU BHA #15 & bit #21; 29 6/2/78 12,345'TD ll8' Footage 9 5/8" window 10,257'- 10,313' Completed RIH w/ Bit #21 & BHA #15. 8 1/2" hole 12,227'-12,345' (6 hrs). PU'BHA #16 & Bit #22. TIH. Directionally drilled Pooh for BHA change. 30 6/3/78 12,487'TD 142' Footage 9 5/8" window 10,257'- 10,313' Directionally drilled 8 1/2" hole 12,345'-12,487'. for DD Run #7. PU DD, BHA #17 & Bil~ #23. TIH. Pooh 31 6/4/78 12,631 'TD 144' Footage 9 5/8" window 10,257'- 10,313' RIH w/ EAstman DOT steering tool in Dialog W.L. & oriented DD #7 80v left from high side of hole. DD 12,497'-12,540'. Pooh. RIH w/ Bit #24 & BHA #18. Drilled 8 1/2" hole 12,540'-12,631 '. Pooh. 14. I hereby/L~r~y ~ha, the fi;~'g~ing,,.~ ~u~a./~orrec! ./-:C7 ....... ~- ~ ~ ' : ~ /~z/~~ u~s~. ur~g. ,uvc. 7/14/78 SIGNED~'~//.~ ~. ~~~~~LE DATE / ''-Jim-P__ (all~nn~r 'Z"-*~~ NOT'Ream on this form is required for e~lendar month, regardlem of the matus of operatiom, and mum be fil~ in duplicate with the /~ oil and ~s conservation committ~ by the 15th of the succe~ing month,unl~ otherwise dir~t~. . - 32 6/5/78 33 6/6/78 34 6/7/78 35 6/8/78 36 6/9/78 37 6/10/78 38 6/11/78 39 6/12/78 12,877'TD 246' Footage 9 5/8" window 10,257'- 10,313' 13,132'TD 255' Footage 9 5/8" window 10,257'- 10,313 13,339'TD 207' Footage 9 5/8" window 10,257'- 10,313' 13,536'TD 197! Footage 9 5/8" window 10,257'- 10,313' 13,800' TD 264' Footage 9 5/8" w.i ndow 10,257'- 10,313' 13,800' TD O' Footage. 9 5/8" window 10,257'- 10,313' 13,800' TD O' Footage 9 5/8" window 10,257'- 10,313' 13,800'TD O' Footage 9 5/8" window 10,257'- 10,313' Finished pooh. RU BHA #19 & Bit #25. RIH. Drlg'8 1/2" hole 12,631'-12,877' (13 1/2 hrs). PoOh. Finished pooh..RIH w/ Bit #26 & BHA #19. Drlg 8 1/2" hole f/ 12,877'-13,132'. Dropped survey. Finished pooh. RIH w/ Bit #27 & BHA #20. Directionally drld 8 1/2" hole from 13,132'-13,339'. (10 hrs). Experienced high torque 13,314'-13,339'. Pooh. PU Bit #28 & BHA #21. Finished RIH w/ Bit #28 & BHA #21. Directionally drld 13,339'-13,519'. Pooh. RIH w/ Bit #29 & BHA #22. Directionally drld 13,519'-13,536'. Drld 8 1/2" hole from 13,536'-13,725" w/ Bit #29 on BHA #22. (206' - 7 1/2 hrs : 27.5'/hr - Smith F-2 Bit). TIH w/ 8 1/2" Bit #30 on BHA #22,- hole cond. good. Drld from 13,725' to TD @13,800'. (75' - ~ hrs = 19'/hr - Smith F-2 Bit). Made wiper trip - hole cond. good. Circ. & cond. mud to log. Dropped survey & pooh. RU Schlumberger. Ran DIL-GR log. Schlumberger checked Drillers TD of 13,800' @13,797' W.L.M. Logged DIL-GR from 13,797'-12,450'. Schlumberger unit slipped on surface while logging out of hole @12,450' - good log to 12,450'. Ran DIL-GR back to 13,405' & wall stuck Sonde 13,405'. RU fishing tools, cut & stripped over Schlumberger W.L. Worked overshot over top of Sonde @13,402' DPM. Differentially stuck DP while engaging fish & worked DP free. Pooh w/ W.L. & fish on 5" DP.. LD fishing tools & fish. RIH w/ BHA #23 & Bit #31. Broke circ. in stages @5,000' & 10,000'. Circ. out bridges 13,302'-13,332'. Ran into 13,800' & circ out gas cut mud (71# in - 61# out). Circ & cond mud for 7" liner - mud not responding properly to chemicals. Pulled up into 9 5/8" csg. Circ & cond. mud for 6 hrs. RIH to 13,800' (hole cond good). Circ & cond mud & hole @13,800' for 7" liner. qb ~ ~ 6/13~78 41 6/14/78 42 6/15/78 43 6/16/78 44 6/17/78 45 6/18/78 1 3,800' TD 9 5/8" window 10,257'- 10,313' 7" liner 9746'- 13,782' Compl circ. & cond. mod. Pooh. RU & ran 97 j ts 7" 29# N-80 Butt. csg. on TIH hydro-hanger. Differentially stuck 7" liner while picking up circ. head w/ liner shoe hung @13,782' (18' off .btm). Top of liner hanger @9746'. Liner figures subject to change slightly after DP strap. Broke circ & circ 20F~% capacity of DP & 7" liner - o.k. Dropped shear-out ball to set 7" liner hanger. 13,800'TD Hung 7" liner on TIW hydro-hanger w/ shoe @13,782', F,C. 13,734'ETD FC @1~.~7~4' & top of tie back sleeve @9746'. Cemented 7" 9 5/8" window 'liner w/ 700 sx. C! "G" cmt w/ .75% D-31, .3% D-19 & 10,257'- .1% D-6 mixed @ll8#/cu.ft. Pumped 200 c.f. FIW ahead, 10,313' 7" displaced w/ mud. Bumped plug w/ 2500 psi (displacement liner 9746'- high). CIP @03:50 hrs 6/14/78. Released from hanger - 13,782' had slight flow back. Pooh. PU 8 1/2" Bit & 9 5/8" csg scraper & RIH & tagged liner top @9746' (no cmt. on top of liner). Pooh. RIH w/ Baker ret. pkr. & test valve. Set pkr. @9708' & opened test Valve. Tested liner lap - no good. (had hard blow for 10 min). Pulled pkr loose. 13,800'TD Pulled up to 96~9' & set pkr. RU Howco & established 13,734'ETD FC break down rate of 10 CF/min & 2200 psi. Squeezed 9 5/8" window liner lap W/ 200 sx Cl "G" cmt. w/ .75% D-31, .3% D-19 10,257'- & .1% D-6 mixed @ll8/cu.ft. Pumped 100 CF wate~ ahead 10,313' 7" & 50 CF behind. Initial sqz. press, of 2000 psi & liner 9746'-.¥ final press, of 3000 psi. CIP @03:05 hrs 6/15/78. Held 13,782' press, on lap until 06'00 hrs (bleed back to 1750 psi). Pooh. RIH w/ 8 1/2" bit &9 5/8" csg. scraper. Tagged cmt. @9659'. C.O. cmt. from 9659' -9746'. Pooh PU Baker test tools. 1 3,800' TD 13,678'ETD FC (corr) 9 5/8" window 10,257'- 10,313' 7" liner 9734'- 13,770 (corr) 13,800' TO 13,673'ETD FC Set Baker test pkr ~9636' & opened test tools to dry test lap. ~Io good. RU Howco & squeezed lap w/ 200 sx C1 "G" cmt w/ ~75% D-31, .3% D-19 & .1% .0-6 mixed @ llS#/cu.ft. Pumped 100 c.f. water ahead & 50 c.f. behind. Final press of 4500 psi. CIP @07'35 hrs 6/16/78. Held press on lap 4 hrs. (Press bled back to 3100 psi). Pooh. RIH w/ 8 1/2" bit & 9 5/8" csg scraper. Tagged cmt ~9730'. C.O.'cmt 9730' -9734'. Pooh. RIH w/ Baker test tools. Set pkr 9625'. Put 1200 psi gas cushion on DP. Opened tester, bled off DP, had light blow corr 9 5/8" for 5 min then no blow for 1 hr. Pressured up DP to window 10,25'7'- 360~ psi (bled back to 320~ psi after 30 min lap - o.k.). 10,313' 7" Pooh. RIH~w/ 6 1/8" bit & tagged cmt @9734'. C.O. cmt liner 9734'- from 9734'-9904' .q from 13,63~'-13,678' (TIW plug 13,,770' (corr) catcher ETD). Pooh. 13,800'TD 13,673'ETD FC (corr) 9 5/8" window 10,257'- 10,313' 7" liner 9734'- 13,770' (corr) RU Schlumberger. Schlumberger checked ETD float collar @13,678' WLM. Ran FDC-CNL log. RD Schlumberger. R.I D.A. Ran CBL, Signature log & Eastman gyro. 46 47 48 49 50 6/19/78 6/20/78 6/21/78 6/22/78 6/23/78 1 3,800 ' TD 13,678' ETD FC 9 5/8" window 10,257' - 10,313' 7" liner 9734'- 13,770' 13,800' TD 1 3,678' ETD FC 9 5/8" window 10,257'- 10,313' 7" liner 9734'- 13,770' 13,800 ' TD 13,678' ETD FC 9 5/8" window 10,257'- 10,313' 7" liner 9734'- 13,770' 13,800'TD 13,678' ETD FC 9 5/8" window 10,257'- 10,313' 7" liner 9734'- 13,770' 13,800 ' TO 1 3,678'ETD FC 9 5/8" window 10,257'- 10,313' 7" liner 9734'- 13,770' RIH w/ Baker ret. pkr. on 3 1/2" DP stinger on 5" DP. Set pkr @13,331'. RU D.A. & RIH 2 3/8" gun on W.L. to 13,410'. Gun misfired Pooh. RIH w/ new gun. Perf 4 HPF from 13,410'-13,412' (8 holes). Est. pump in rate of 6 CFM @6500 psi (broke back to 3200 psi pumps off). Squeezed perfs from 13,410'-13,412' w/ 50 sx. C1 "G" cmt. Final press, of 7000 psi. CIP @1430 hrs 6/19/78. Rev. clean. PU to 12,650' & set pkr. RIH w/ 2 3/8" gun on W.L. to 13,014'. Gun misfired. Pooh w/ gun. Tested sqz. #1 from 13,410'-13,412' @5000 psi.- o.k. RIH w/ 2 3/8" gun & perf 4 HPF from 13,014'-13,016' (8 holes ). Pooh w/ D.A. Set pkr @12,987'. Est. pump in rate of 6 CFM @5600 psi (3700 psi pumps off). Squeezed perfs (Base Hemlock Bench #1) from 13,014'-13,016' w/ 57 sx C1 "G" cmt w/ .75% D-31, .3% D-19 & .1% D-6. Final press, of 6200 psi. CIP @0305 hrs 6/20/78. Rev. clean. WOC8 hrs. PU to 12,806'. Set pkr & tested sqz to 5600 psi - o.k. RIH w/ D A. & shot 4 HPF from.l~,972'- 12,974' (top of Hemlock Bench #1). (8 holes). Set pkr @12,900'. Est. pump in rate of 9 CFM @6400 psi (3200 psi pump off). Squeezed perfs from 12,972'-12,974' w/ 100 sx C1 "G" cmt w/ .75% D-31, .3% D-19 .1% D-6. Final press, of 5500 psi. CIP @20'30 hrs 6/20/78. Rev. clean. Finished pooh-w/ sqz. tools. RIH w/ 6" bit on 90' of 4 3/4" collars. C.O. cmt. from sqz. jobs #3, #2 & #1 (i.e. hard cmt. from 12,925'-12,976', 13,000' to 13,060' & 13,320'-13,508' respectively). Pooh. Set Baker 7" test tool @12,895' above Hemlock Bench #1 & #4 W.S.O. sqz. perfs. Loaded DP w/ 1000 psi water cushion & opened tester - had light blow diminishing for 1 hr. Rev. out & rec. approx. 10 CF excess fluid. Dry test on sqz. perfs - o.k. Pooh. Ran 9 5/8" Baker retrievamatic sqz. tool to isolate & test leak reported in 9 5/8" csg. between 6972',,& 6987'. Set tool @7177' Tested 9 5/8" csg, liner lap & 7 below tool to 3500 psi (iO0 psi bleed off in 30 mins) - held o.k. Tested 9 5/8" csg above te 3000 psi - held'o;k, Reset tool @6770' (above casing leak) & tested below to 3500 psi. Bled to 3475 in 30 mins - test o.k. Will eliminate 7" csg tie-back string. Pooh w/ 9 5/8" tester. ~aited 71 hrs on transportation to haul completion equipment. Changed mud over to FIL~ @ETD & spotted 50 bbls Dril-S on btm. 51 52 6/24/78 6/25/78 13,800' TD 13,678' ETD FC 9 5/8" window 10,257'- 10,313' 7" liner 9734 - 13,770' 13,800'TD 13,678' ETD FC 9 5/8" window 10,257'- 10,31 3' 7" liner 9734 - -13,770' Ran & set Baker Model "F" pkr @12,855' on W.L. (DIL measurements ). Changed pipe rams to 3 1/2". Off loaded prod. equipment. 53 6/26/78 13,800'TD Ran 3 1/2" 9.2# N-80 w/ Atlas Bradford modified 13,678'ETD FC couplings. Stabbed into Baker perm pkr @12,855' Otis 9 5/8" window "X" @12,911', "XA" @12,827', mule shoe @12,941', Camco 10,257'- TRB-6 ball valve @299'. Removed BOPE stack. Installed 10,313' 7" & tested CIW tree. liner 9734 - 13,770' ~- 54 6/27/78 13,800' TD 13,678' ETD FC 9 5/8" window 10,257'- 10,313' 7" liner 9734 - 13,770' RU D.A. vamp fl owline. Gas lifted FIW from annul us to GLV #15 (recovered 777 bbls FIW). Put 2000 psi water cushion on tbg. 55 .6/28/78 13,800' TD 13,678' ETD FC 9 5/8" window 10,257'- 10,313' 7" liner 9734'- 13,770' Perf 4-1/2" HPF from 13,390'-13,265' w/ D.A. 2 5/8" tbg guns (6 runs - no misfires). Shot all holes wi th well on gas lift. 56 6/29/78 13,800!TD 13,678'ETD FC 9 5/8" window 10,257~- 10,313~ 7" liner 9734 - 13,770! RD DA. Placed well on production @00:45 hrs 6/29/78 for testing, Shut in well @16:00 hfs 6/29/78. RIH w/ btm hole press recorder to 13,327'. Put well on production for 1 hr drawdown @19-15 hrs. Shut in for build up @21:00 hrs. 57 6/30/78 13,800'TD 13,678' ETD FC 9 5/8" window 10,257' - 10,313' 7" liner 9734'- 13,770' Completed 24 hr press build up. Fco:m 10-40~'~ Submit *'Intentions" in Triplicate REV. 1-10-73 & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 1. OwlELLLDWELLGAS D OTHER NAME O,F OJ3ERA~Q~{ union ulI Company of California 5. APl NUMERICAL CODE 50-133-20116-02 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 6247, Anchorage, AK 99502 TBUS G-12RD-2 10. FIELD AND POOL, OR WILDCAT McArthur River Field 4. LOCATION OF WELL At surfaceGrayling Platform Conductor 37 Leg 2 1874'N & 1386'W of SE corner of Sec. 29, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RT gg' ahnve MSI Check Appropriate Box. To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, Rt3W, S.M. 12. PERMIT NO. 78-42 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [__ FRACTURE TREAT SHOOT ORACIDIZE REPAIR WELL ' (Other) PULL OR ALTER CASING k-....J MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RII~'G WELL FRACTURE TREATMEN'IL ALTERIN(~ CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE.. Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. TBUS G-12RD-2 was originally proposed as a Hemlock Zone water injector. It is now proposed to complete TBUS G-12RD-2 as a single zone Hemlock oil producer with BenChes #1 and #4 perforated for production. NOTE' This well is in excess of 1000' from any producing well in the proposed completion and conforms to the 160 acre spacing requirements as per Bob Warthen, Union Oil Company District Geologist. 16. I hereby c~rtlfy~that the forego~J~%g is true and correct // dim R. Callender Dist. Drlg. Supt. TITLE (This spa(~or State office use) , CONDITIONS OF APPROV~'L, I : ~. TITLE See Instructions On Reverse Side DATE 6~22/78 ApProved Copy Returned Form No. P-4 ~EV. 3- 1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Co. of Calif. 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL 10. Grayling Platform Conductor 37, Leg 2, 1874'N & 1386'W of SE corner of Section 29, T9N, R13W, S.M. Il. 12. 5. APl NUMERICAL CODE 50-133-20116 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBUS G-12RD-2 (34,33) FIELD AND POOL, OR WILDCAT ~ McArthur River-Hemlock SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 33, T9N, R13~J, S.M.'. PERMIT NO. 68-44 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 5/5/78 5/6/78 13,710'TD 12,700'ETD (cmt) 9 5/8" window 12,420'- 12,480' 7" liner 13,709'- 12,272' (7" tie back to surface) 13,710'TD 12,700'ETD (cmt) 9 5/8" window 12,420'- 12,480'. 7" liner 13,709'- 12,272' (7" tie back to surface)' RU rig 54 over conductor 37 in leg room 2. Loaded 3 1/2" x 7" annulus w/ FIW and circ. hole down annulus w/ returns out tbg until rec. clear water returns. Installed BPV & removed CIW 3 1/2" double valve single block X-mas tree. Installed and tested to UOCO specs 12" 3000 psi BOPE. Pulled 3 1/2" seal assy out of perm pkr @12,800' and circ. hole w/ FIW. Pulled and LD 423 its 3 1/2" tbg w/ G.L. mandrels. Loaded tbg & X-mas tree on boat and sent to beach for inspection & repair. Dist. Drlg. Supt. DATE 6/15/78 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be f/led in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. 5/7/78 5/8/78 5/9/78 5/10/78 5/11/78 13,710'TD 12,700'ETD (cmt) 9 5/8" wi ndow 12,420'- 12,480' 7" 1 iner 13,709'- 12,272' (7" tie back to surface) Ran 6" bit, 7" csg scraper & three 4 3/4" DC on 3 1/2" G.E. & S-135 DP to perm pkr @12,806' DPM. Circ. hole w/ FIW and pooh w/ DP. Hole taking +50 bbl/hr FIW. Ran 7" Howco cmt ret on 3 1/2" DP and set @12,750'. Tested 7" csg above ret to 1500 psi. Squeezed for abandonment Hemlock Benches 1-4 perfs 12,902'-13,356' w/ 250 sx Cl "G" w/ .75% D-31 to a final pressure of 3500 psi. Pulled out of ret and dumped 10 sx cmt on ret. from 12,750'-12,700'. Pulled DP to 12,700' and rev. hole clean. 13,710'TD Finished reversing out from 12,700' after squeeze'job and 12,700'ETD pooh. Ran Tri-State 7" mechanical inside casing cutter on (cmt plug) 5" DP and cut 7" csg @10,406'. Closed BOPE. and unable to break 9 5/8" window circ. thru 7" x 9 5/8" annulus @2500 psi. Cut 7" csg @10,407' 12,420'- and unable to break circ. Pooh and found blades on cutters 12,480' 7" rounded and worn out indicating no cut on csg. Redressed liner 13,709'- cutter and RIH on 5" DP. Cut 7" csg @10,386' and unable 12,272' (7" to break circ. thru 7" x 9 5/8" annulus @3000 psi. Pooh and tie back tO cutter o.k. - indicated cut on 7" csg. Picked L~p BOPE. Ran surface) Tri-State 7" Model B casing spear and engaged 7'~ csg. Picked up on csg @300,000# hook load and removed slips. Slacked off on 7" csg and released spear. 13,710'TD Pooh w/ spear after removing 7" csg slips. Removed CIW 10" 12,700'ETD 5000 x 12" 3000 psi DC tbg spoOl. NU 12" 3000 psi spacer spool (cmt plug) and 12" 3000 psi BOPE. Tested BOPE to 3000 psi w/ 200 psi 9 5/8" window leakoff in 5 min (csg leak in 9 5/8" csg @+6965'). Dialog 12,420'- perf 7" csg w/ 4 holes @10,348'. Ran 7" sp-ea,r, and engaged 7" 12,480' 7" csg. Unable to break circ down 7" csg thru 7 x 9 5/8" annulus stub @10,386' @3000 psi. Pressured 7" csg to 2000 psi and pulled csg up hole w/ 420,000# hook load. Pulled and LD 3 its 7" csg w/ max of 550,000# hook load and 2700 psi on csg. Cut drlg line & repaired csg slips. 13,710!TD 12,700' ETD (cmt plug) 9 5/8" window 12,420'- 12,480' 7" csg stub @10,386' Continued to pull and LD 7" csg @450-500,000# hook load holding 2700 psi on 7". csg for total of 28 its (+9200'). Pulled and LD total of 66 jts (+7600') @450-500,000~ hook load without pressuring csg. Broke circ. down 7" csg. and thru 7" x 9 5/8" annulus @7600' and circ hole clean w/ FIW. Finished pulling & LD total of 248 its + 2 pieces 7" 29# N-80 csg in excellent condition. RD csg tools. Ran 8 1/2" bit and 9 5/8" csg. scraper on three 4 3/4" DC and 3 1/2" DP. 13,710'TD Finished RIH w/ 8 1/2" bit & 9 5/8" csg scraper on 3 1/2" DP lO,345'ETD to top of 7" stub @10,391' DPM. Circ hole clean w/ FIW. (cmt ret) Pooh & LD 3 1/2" DP. Ran Eastman gyro survey on Dialog W.L. 9 5/8" window from 10,391'-600'. Perf 9 5/8" csg w/ 4 holes @10,370'. 12,420'- Ran 9 5/8" Howco cmt ret on W.L. & set @10,345'. 12,480' 7" csg stub @10,386' 10 11 12 5/12/78 5/13/78 5/14/78 5/15/78 5/16/78 13,710'TD Finished pooh w/ W.L. after setting 9 5/8" cmt. ret. @10,345'. lO,345'PBTD Ran Howco stinger picking up 5" DP and stabbed into ret. (cmt ret) @10,345' Squeezed holes @10,370' for milling section w/ 250 sx 9 5/8" window C1 "G" w~ .75% D-31, .3% D-19, .1% D-6 & 10% sand to a final 10,257'- pressure of 3850 psi. Pulled out of ret and rev. hole clean. 10,262' Pooh Perf 9 5/8" csg w/ 4 holes @10,280'. Ran 9 5,/8'' Howco RTTS retrievable pkr on 5" DP to +_10,000' and WOC' 13,710'TD Squeeze @10,370' for total of 12 hrs. RIH & set RTTS @lO,114' lO,345'PBTD Broke down .squeeze perfs @10,280' @3000 psi and PI @6 CFM (cmt ret) & 3000 psi. Squeezed perfs @10,280' for milling section w/ 9 5/8" window 150 sx. C1 "G" w/ .75% D-31, .3% D-19, .1% D-6 & 10% sand to 10,257'- a final press, of 4200 psi. Squeeze held 3950 psi after 10,262' 35 min. Released press, and rev. hole clean. Pooh. Ran 8 1/2" bit & 9 5/8" csg. scraper on 5" DP a.nd drilled out hard cmt. from 10,118'-10,280' (stringers to 10,345'). Circ. hole clean and pooh. Results from Eastman gyro survey run 5/11/78 moved KOP [a10,250' approx. 1100' @S46N. RU Dialog to run Sperry-Sun surface readout gyro survey and could not get tools working in 4 ~hrs. 13,710'TD RD Dialog. Ran 8 1/2" bit on 5" DP to 10,345' and displaced lO,345'PBTD 9 5/8" csg w/ pre-mixed fresh water prehydrated gel-FIW mud. (cmt ret) Circ. and cond. mud to +70 vis. Pooh. RU Dialog and ran 9 5/8" window Sperry Sun conventional-gyro survey from 10,345'-600'. Ran 10,257'- 9 5/8" Servco section mill & five 6 1/4" DC on 5" DP to 10,257'. 10,262' Cut 9.5/8" csg. and milled section in 9 5/8" csg from 10,257'- 10,262' in 3 1/2 hrs. Sperry Sun check gyro confirms KOP location indicated by Eastman gyro. 13,710'TD Continued milling section in 9 5/8" csg from 10,262'-10,269' lO,345'PBTD in 3 1/2 hrs w/ mill #1. Circ hole clean and pooh. Drag (cmt ret) increased w/ section mill @+10,150' (100' into 9 5/8" csg) 9 5/8" window on trip out. Worked pipe an-d circ bottoms up to clear hole 10,257'- of metal cuttings. Ran 9 5/8" Servco section mill #2 & five - 10,286' 6 1/4" DC on 5" DP to 10,267'. Reamed 2' to 9 5/8" stub and milled section from 10,269'-10,286' in 9 1/2 hrs. (cmt ret) 9 5/8" window 10,257' 10,313' 13,710'TD After milling 9 5/8" section from 10,269'-10,286' 10,345'-PBTD w/ mill ~2 circ hole clean and pooh. Drag increased w/ section mill @ +10,150' (100' inside 9 5/8" csg) on trip out. Worked free by working pipe and pumping bottoms up. Ran 9 5/8" Servco section mill #3 and five - 6 1/4" DC on 5" DP to 10,285'. Reamed 1' to 9 5/8" stub and finished milling section from 10,286'-10,313' in 7 1/2 hrs. Total 9 5/8" section 10,257'-10,313' (56'). Circ hole clean and pooh. ~ Ran +300' 3 1/2" DP open ended stinger on 5" DP. 13 14 15 16 17 5/17/78 5/18/79 5/19/78 5/20/78 5/2i/78 13,710'TD Finished RIH w/ +300' 3 1/2" DP open ended stinger 10,100'PBTD on 5" DP to cmt.--ret. @10,345' in 9 5/8" csg. (cmt plug) below stub. Circ. bottoms up and displaced 9 5/8" 9 5/8" csg. w/ FIW. Spotted 125 sx. C1 "G" cmt w/ 75% D-31 window and 10% sand mixed @120#/cu.ft. from 10,345' to 10,257'- +10,100'. Pulled DP to 10,000' and squeezed 10 cu.ft. 10,313' c--mt, away to 1,000 psi. Bled off pressure and pooh. Set 9 5/8" Baker ret. BP @576'. Tested 12" 3000 psi BOPE to 3000 psi as per Union specs. - test witnessed by DOG representative. Retrieved BP. Ran · 8 1/2" bit & five 6 1/4'.' DC on 5" DP and CO cmt. in 9 5/8" csg. from 10,081'-10,100'. 10,307'TD Continued dressing off cmt. KO plug in 9 5/8" csg. 50' Footage from 10,100'-10,277'. WOC total of 24 ~hrs and 9 5/8" finished dressing off plug t© 10,262' ('5' below top window of window). Circ hole clean and pooh. Ran 8 1/2" bit 10,257'- & DD BHA #3 on 5" DP to 10,250'. RU Eastman D.O.T. 10,313' steering tool on Dialog W. and oriented tool for left hand turn @ 80 deg. left from high side of hole. DD 8 1/2" hole from 10,262'-10,307'. Displaced FIW in hole w/ fresh water prehydrated gel-FIW~'system while DD @10,277'. 10,771'TD 464' Footage 9 5/8" window 10,257'- 10,313' Continued DD 8 1/2" hole 10,307'-10,320' to kick off through 9 5/8" window. Pooh for new bit. Ran ~ 1/2" bit #7 & DD BHA #4 on 5" DP to 10,320'. RU Eastman D.O.T. steering tool on Dialog W.L. and oriented tool for left turn @70 deg left of high side of hole. DD 8 1/2" hole 10,320'-10,370' and pooh for follow-up assy. Ran 8 1/2" bit #8 & follow up BHA #5 on 5" DP. 10,771'TD 464' Footage 9 5/8" window 10,257'- 10,313' Reamed DD hole 10,257'-10,370'. Drld & surveyed 8 1/2" hole 10,370'-10,551' &_pooh for DD. Ran 8 1/2" bit #9 & DD BHA #6 on 5" DP to 10,551'. 10,771'TD 464' Footage 9 5/8" window 10,257'- 10,313' RU Eastman D.O.T. steering tool on Dialog W.L. & oriented tools for left turn @80 deg. left of high side of hole. DD 8 1/2" hole 10,551'-10,610'. Pooh for follow-up BHA. Ran 8 1/2" bit #10 & follow-up BHA #7 on 5" DP and reamed DD hole 10,551'-10,587'. Reamed thru tight spot @10,560'-10,565' second time and stuck pipe - jarred free in 1 hr. Reamed DD hole 10,551'-10,610'. Drld & surveyed 8 1/2" hole 10,610'-10,771'. 18 19 2O 21 22 23 24 25 5/22/78 5/23/78 5/24/78 5/25/78 5/26/78 5/27/78 5/28/78 5/29/78 10,997'TD Continued drlg & surveyed 8 1/2" hole w/ bit #10 & 226' Footage BHA #7 10,771'-10,775'. Pooh to lock up BHA. Ran 9 5/8" 8 1/2" bit #11 & locked BHA #8 on 5" DP and reamed window DD hole 10,257'-10,370' & 10,551'-10,610'. Drld 10,257'- & surveyed 8 1/2" hole 10,775'-10,997'. Pooh for 10,313' DD to turn course left. Ran 8 1/2" bit #12 on DD BHA #9. ll,216'TD Finished RIH w/ DD BHA ~9 to 10,997'. Ran Eastman 219'Footage D.O.T. steering tool on Dialog W.L. and orient 9 5/8" for left turn @80 deg. left of high side of hole. window DD 8 1/2" hole 10,997'-11,087' and pooh. Ran 8 1/2" 10,257'- bit #1.3 & locked BHA ~10 on 5" DP and reamed DD 10,313' hole 10,997'-11,087'. Drld & surveyed 8 1/2" hole 11,087'-11,216'. 11,458'TD Drld & surveyed 8 1/2" hole from 11,216'-11,236' 242'Footage w/ bit #13 & BHA #10. Pooh for new bit. Rsn 8 1/2" 9 5/8" bit #14 & BHA #10 on 5" DP and drilled from 11,236'- window 11,458'. Dropped survey and pooh. Had some excess 10,257'- drag on trip out. RIH to 5000' and circ. to cond. 10,313' mud. 11,458' TD O' Footage 9 5/8" window 10,257'- 10,313' RIH w/ 8 1/2" bit #15 & BHA #11 to 5000' and circ to cond mud. Pilot tests on mud indicate contaminant in system. RIH to 10,200' and circ to cond mud. Mud failing to react to chemical treatment for contamination. 11,458'TD O' Footage 9 5/8" window 10,257'- 10,313' Circ & cond mud @10,200' - mud failed to respond to chemical treatment for contamination. Built new fresh water prehydrate( gel mud in surface system and displaced hole w/ new mud. Circ & cond mud to 70#/cu.ft. wt, 25#/bbl CEC & 10 CC FL in 12 hrs. 11,594'TD 136' Footage 9 5/8" ' window 10,257'- 10,313' RIH & washed and reamed as necessary @10,648'-10,716', 10,910'- 11,014', 11,099'-11,202' and 11,229'-11,458' in 5 hrs. Drld & surveyed 8. 1/2" hole w/ bit #15 & BHA #11 from 11,458'- 11,594' in 7 1/2'hrs-and bit locked. Pulled into 9 5/8" csg @10,257' & circ to cond mud for survey by diluting w/ FIW and SAPP. ll ,656'TD 62' Footage 9 5/8" window 10,257'- 10,313' Staged in hole to 11,594' w/ no problems and circ bottoms up. Ran W.L. directional survey and pooh for new bit. RIH w/ 8 1/2" bit #16 & BHA #11 on 5" DP - hole in good cond. Drld 8 1/2" hole 11,594'--11,656'. 11,782' TD 126' Footage 9 5/8" window 10,257'- 10,313' Drilled 11,656'-11,750' in 8 1/2 hrs and lost pump pressure. Pooh to washout in slip area of 34th jt 5" S-135 DP (+__1,060'). LD washed out jt and RIH to 11,750'. Circ bottoms up and ran W.L. directional survey. Pooh for DD. Ran 8 1/2" bit #17 & DD BHA #12 on 5" DP to 11,750'. RU Eastman DOT steering tool on Dialog W.L. and oriented tool to 80 deg. left from high side of hole for max .left turn. DD 8 1/2" hole 11,750'-11,782' in 3 1/2 hrs. 26 27 5/30/78 5/31/78 ll ,920'TD 138' Footage 9 5/8" window 10,257'- 10,313' 12,147'TD Footage 227' 9 5/8" window 10,257'- 10,31'3' Continued DD for maximum left hand turn from 11,782'-11,797'. (Total DD Run #5 11,750'-11,797' - 47' in 5 hrs). Pooh w/ DD. TIH w/ 8 1/2" bit #18 on follow-up BHA #13. Reamed DD run & drld 8 1/2" hole to 11,920'. Dropped survey & pooh - hole tight @11,824'. TIH w/ 8 1/2" bit #19 (Smith F-2) on BHA #13. Completed TIH w/ Bit #19 on BHA #13. Drld 8 1/2" hole from 11,920'-12,147' (Smith F-2 bit 227' in 11 1/2 hrs ~ 1~ 7'/hr)' Ran survey @12,147'. Instrument depth 12,102' 41./26'S36°~. Hole had-turned back 5o right in 227'. Pooh. 'PU 8 1/2" Christensen MD-41 S.T. Diamond Bit #20 on BHA #14 & TIH for DD run #6. DF~r~I~f OF. }~AA~OI'~AL P~SO~ Division of Oil and Gas Conservation O. K. Gi!breth, Jr~^~' Director Hoyle H. Ham~lt~a ~~ Chief Petroleum Engineer~ -' June 2, 1978 Witness BOP Test, Unicm Oil Grayling Platform, Sec. 29, T9N, Rl~4, C~-12 TBU P~drill, Permit No. 78-42 ~sday, May ~7_, _1978 - I left _Anch?r? by ~f[ at 7:00 AM to Y~nai arr~-Vln~-~ ~ at 7:30 AM and Era helipo~c North Kenai by Avis R~nt A Car. I arrived cm th~ Grayling platform at 8:45 AM. Purpose of trip to witness BOP t~st on %~11 G-12 TBU redrill. I met Larry Graham, operator for Union Oil. Tests starbed at 12 no~n and finished at 8:15 PM. With blind rams closed, inside choke, insidm kill were tested to 3000 psi OK. With blinds still closed, outside kill and HCR valve w~e tested to 3000 psi. Check valve was disabled and put back tog~ and tested to 3000 psi. ~ test stem was put in and. the upper pipe rams, 3 valves on choke manifold ~ tested to 3000 psi. Wi~] upp~_r pipes still closed, 3 r~Dre valves on manifold w~re tested to 3000 psi. One m~re valve plus tP~ Swaco superchoke was tested to 3000 psi. M~nual chokm ~s froze up solid, ~as repaired and working C~. Lc~r pipe rams had to be chan~ ~ and tested to 3000 psi. The annular pr~nter was tested next to 1500 psi. The upper and lc~ar kelly ~ tested to 3000 psi. ~ kelly leaked first test and ~s repaired. There a ball mid dart ~alve om flo~r OK. The acctm~alator ~as 2600 ~n master, but I performmnce te~ accumulator and master psi stayed ~ 1200 psi OK. The N, backup was 2200, 2200, 2200 and 2300 each. There ~re two failur~ on tests that ~re repaired and tested C~. ~_~3 I witnessed the BOP test ~n G-12 TBU for Union Oil. When tests w~re finished BOP's and all o~~ts tested sa~_isfactorily. Ala Opera Satisfactory Type Inspection Yes No Item ( ) Location,General () () () () () () () () () () () () Yes No 1. Well Sign 0() ( ) 2. General Housekeepin.Q ()~ ( ) 3. Reserve Pit-( )open( )filled .(X)- ( ) 4. Rig0~} ( ) Oil and Gas Conservation Commit Field Inspection Report ll~l~tl/Platfm Sec]~? Represented by~_~t~&~ A~.~I,.A.,~..A..~,m~ & Number~-~! Satisfactory T.~pe Inspection Item (~ BOPE Tests 15 ~,~-'.'Casi-nq set 16 T'~-~$~ fluid-(N)wtr.+-/-(- )mud ( ) oil ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 17 18 (~0 ( ) 19 (2~) ( ) 20 (~) ( ) 21 (X') ( ) 22 () 24 (X) () 25 ( ) ( ) 7. Well Nos. ( ) ( ) 8. Hrs. obser' ( ) ( ) 9. BS&W , Master Hyd. Control Sys.-.~'O. psig ~'!2 btl s .~,~la~,O~,]~_,:z]~PS l .Q Remote Controls Drilling spool- ]~/! "outlets Kill Line-(20 Check valve Choke Flowline ~)K') HCR valve Choke Manifold No. valvsJ;$'~ flgs~__ Chokes-(X) Remote (~ Pos. ~-~d j Test Pluo-( )Wellhd~)csq'( )none ( ) ( ) lO. Gr. Bbls. , , , C>~) ( ) 26 Annular Preventer~,IT_O_g_psiQ ( ) Final Abandonment (~ ( ) 27 Blind Rams~r~opsi~ ( ) ( ) l l. P&A Marker - . ( ) 28 Pipe Rams~d.~,O psiq ( ) ( ) 12. Water well-( )capped( )plugged (;() ( ) 29 Kelly & Kelly-cock~oo~)psig ( ) ( ) 13. Clean-up ~ ( ) 30 Lower Kelly valve~ops~/~ ( ) ( ) 14. Pad leveled ~ ( ) 31 Safety Floor valve~BV~ )Dart Total inspection observation time_~/days Total number leaks and/or equip, failures_~ Remarks ~ 0 ~ ~R ~P~ ~ - DH~~ _~_~ ~~~~~--~~~ /F~ inlays or when read.y~ Inspected by~ Notify Form 10-403 ' REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" !p Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OiL 1:71 GAS l---] WELL I,j~J WELL OTHER 2. NAME OF OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL At SUrface Grayling Platform conductor 37, Leg 2, 1874'N & 1386'W of SE corner of Section 29, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20116 6. LEASE DESIGNATION AND SERIAL NO. _ ADL 17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBUS G-12RD (34-33) 10. FIELD AND POOL, OR WILDCAT McArthur River-Heml ock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 33, T9N, R13W, S.M. 12. PERMIT NO. 68-44 . · )ort, or Other Data NOTICE OF INTENTION TO; r-----i i---=I TEST WATER SHUT-OFF J------i PULL OR ALTER CASING I I FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF; WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state alt pertinent details, and give pertinent dates, including estimated date of starting any proposed work. t see attachment APR 1 Division ol Oil 16..~ I hereby ~"-i 't:ertlfY that.. ' / J/r c)the fo~eg~'T~g is,true[~ and correct (This space'for State of~) ~ ,:~. COND~T~ONSOF 'P OVAL ~F AN~ ~ ~ DATE 4/19/78 See Instructions On Reverse Side Sundry Notices and Rep~ts on Wells Page 2 April 19, 1978 The well was originally drilled in 1968 and completed fmom Hemlock Benches 1-4 12,960'-13,685' The well failed to produce at commercial rates and stimulation efforts yielded only small increases. An unsuccessful workover in 1969 revealed formation damage which proved continued production to be unfeasi bl e. The original well was abandoned in November 1969, and redrilled to obtain a new sand face. The redrill was completed in 1970 from Hemlock Benches 1-4 12,902'-13,356'. The current production rate of 961 BPD with 73% water cut yields only 257 BOPD which is below the economic operating limit. A workover and acid stimulation in 1976 yielded only small short-term increases. It is proposed to permanently abandon Hemlock Benches 1-4 in the present wellbore by squeezing perforations @12,902'-13,356' through a cement retainer set @12,750'. A 50' cement plug will be spotted on the cmt ret from 12,750'-12,700' and the 7" casing cut and pulled from TO,400'. The 9 5/8" casing would then be perforated @10,380' and squeezed below a cmt ret set @10,350'. After abandonment a section will be milled in the 9 5/8" casing from 10,250' to 10,310' and an 8 1/2" directional hole drilled to an advantageous injection point in Hemlock Benches 1-4. A Permit to Drill will be submitted containing information pertinent to the proposed redrill. A wellbore sChematic is attached. P. LA.N OF PROCEDURE' 1. Move rig over conductor 37 in leg room 2. 2. Kill well with FIW. Install BOPE as in Diagram #1 and #2 and test to 3000 psi. 3. Pull and lay down 3 1/2" tubing. 4. Set 7" cement retainer on 3 1/2" DP @+12,750' and squeeze for abandonment Hemlock perfs 12,902'-13,356'. 5. Cut and pull 7" casing from +_10,400'. 6. Perforate and squeeze for milling section @10,370' and 10,280'. 7. Mill section in 9 5/8" casing from +10,250'-10,310'. 8. Kick off and drill 8 1/2" directional hole turning course 19 deg. left from Sl9E to S38E and maintaining 43 deg. angle to 13,670'TMD. 9. Run open hole electric logs. 10. Run and cement 7" long string @13,670'. ll. Clean out casing and run CBL log. Perforate and squeeze as necessary for isolation of Hemlock Bench 4. 12. Clean out cement and test squeezes. 13. Perforate Hemlock Bench 4 and run production packer. 14. Run 3 1/2" injection tubing and place well on injection. May 1, 1978 ~ ~ Unit G-12RD-2 Oil ~ of Califc~nia Pezmit ~. 78-42 En~ is ~ a~gro~d appticati~ for pezmit to drill the above refe~~ ~ at a location in ~ 33, Township 9N, P~n~e 1~;, SM. ~11 samples, ~ d~ips, and a mud log are not required. A directional ~y is .~a~y ri~rs ~ Alaska ~ their ~~ systems have been classified as i~t for ~ ~ or migratic~ of anadrcm~ fish. Operations in t/~_se areas az~ subject tm AS 16.50.870 and the regulations prc~ated e2~r~ar~er (Title 5, Alaska 3~~strat/ve Code). Prior to oa~ncing operat/ons ~ ~ ~ oon~ ~ ~ ~_bitat Cooke's office, Depar~Kent of Fish ~ ~. Pollution of ~ waters ~ t~ State is ~ited by AS 46, Chapter 03, Arti~ 7 ~ ~ z~3ula~s prc~~ ted thereunder (Title 18, Alaska ~stra~e ~, ~ 7'0) and ~ the Federal Water Pollution cc~~ ~ a representative of ~ E~partment of Env~tal ~rvation. Purer to AS 38.40, Lo~ ~ ~ State I~ases, the Alaska Department of ~ is being ~fied of ~ is~ of this pezmit to drill. To ~ us in sch~ field work, ~ would appreciate ~our noti~ this office within 48 ~ ~ ~ ~1 'is ~~ .We would also like to be ~ied ~ that a representative of ~ Division may be present to witness ~ng of b~ pr~snter equ~t before surfaoe casing, shoe is drilled. R.T.~ T. Bo Unit G-12RD-2 -2- ~.~y 1, 1978 In the event of ~ic~ or abandonment please gi~ this office adequate advance notificatic~ so tP~t w~ may ham a witness present. Very truly ~, ~le H. ~Itc~ ~mt~er Alaskm Oil and Gas f~nservation ~'ttee I2xc1~ Department of Fish and Gang, Habitat ~cim w/o encl. Deparbment of Env~ntal Cc~~ti~n w/o encl. De~t of Labor~ Supervisor, Labor Law Ccmp~~ Divisic~ w/o enclo FOrm 10-401 SUBMIT IN TRIPLI REV. 1-1-?1 (Other instructions reverse side) la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [-] DEEPEN [-] Redri11 b. TYPE OF ~'~LL Water OIL GAS SINGLE ,,~LL[] ~LLF-1 0T"ER , Injection ZONE E~] 2. NAME OF' OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR .. P. O. Box 7600,. Anchorage, Alaska 99502 4. LOCATION OF WELL Atsur~ace Grayling Platform Conductor 37, Leg 2, 1874' N & 1386'W of SE corner of Section 29, T9N, R13W, S.M. At proposed prod. zone 1400'N & 800~W of SE .corner of Section 33 13. DISTANCE IN blILES AND DIR~ION FROM NEAREST TOWN OR POST OFFICE* 22 miles NW of Kenai MULTIPLE ZONE [] API No. 50-133-20116-02 5. 50-133-20116 ~- OY- 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARbl OR LEASE NAME Tradinq Bay Unit 9. ~LL NO. TBUS G-12RD-2 10.FIELD AND POOL, OR WILDCAT McArthur River-Hemlock 11. SEC., T., R., M., (BOTTObl HOLE OBJECTIVE) Sec 33 T9N, R13W, S.M. l~. 68-44 14. BOND INFORMATION: Statewide United Pacific Insurance Co. B-55372 $100,000.00 TYPE Surety and/or No. Amount 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, mdt, if any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1600! tO O--12 21. ELEVATIONS (Show whether DF, RT, CR, etc.) RT 99' above MSL 16. No. OF ACRES IN LEASE 5,116 19. PROPOSED DEI~TH 4,000'TMD (10,000'TVD 23. PROPOSED CASING AND CEMENTING PROGRAM 17. NO,ACRES ASSIGNED TO THIS WELL 80 20. ROTARY OR CABLE TOOLS 22. APPROX. DATE WORK WILL START May, 1978 SIZEOFHOL~ .S~,ZEOF,CXSI'NG '~$~IGHTPER. FOOT GRADE ] SE~I~GD~il quantityofcement Existino 9 5/8" 40#. 43.5~ N-RD Window lg.?~g - 47# · P-!!O !0,3!0' 8 !/2" 7. 29# -. N-80 !3,670, .... 700 sx .............. See attachments for detailed Plan of Procedure, BOPE Schematics, before and after Wellbore Schematic, and plat of proposed site. ~'~E~ i-!~ IN ABOVE SPACE DESCRIBE PROPOSED PROGRAIvh If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer pro. am. (This space for State office use) /rI CONDITIONS ,OF APPROVAL, iF .ANY: SAblPLES.AND CORE CHIPS REQUIRED [ blUD ~G OTtIER REQUIREMENTS: [] YES ~ NO I [] YES ¢I NO mRECrIONAL SURVEY REQUmED A.P.I. NUMERICAL COnE [] YES D No TITLEILi~triet l,and M~nnger 50-133-20116-02 PERMIT NO. '"'--:" APPROVAL DATE · TITLE APPOVED BY 6/ .~' - - ~See Instruction On Reverse Side ~.~a.¥ 1, 1978 DATE ~'.~aV 1, 1978 Permit to Drill or De~en Page 2 PLAN OF PROCEDURE: 1. Move rig over conductor 37 in leg room 2. 2. Kill well with FIW. Install BOPE as in Diagram #1 and #2 and test to 3000 psi. 3. Pull and lay down 3 1/2" tubing. 4. Set 7" cement retainer on 3 1/2" DP @+12,750' and squeeze for abandonment Hemlock perfs 12,902'-13,356'. 5. Cut and pull 7" casing from +10,400'. 6. Perforate and squeeze for milling section @10,370' and 10,280'. 7. Mill section in 9 5/8" casing from +10,250'-10,310'. 8. Kick off and drill 8 1/2" directional hole turning course 19 deg. left from Sl9E to S38E and maintaining 43 deg.. angle to 13,670'TMD. 9. Run open hole electric logs. 10. Run and cement 7" long string @13,670'. ll. Clean out casing and run CBL log. Perforate and squeeze as necessary for isolation of Hemlock Bench 4. 12. Clean out cement and test squeezes. 13. Perforate Hemlock Bench 4 and run production packer. 14. Run 3 1/2" injection tubing and place well on injection. . DI,4~ R t~ Yl No i ,Sc H£~,I)-I-IC FOR,: G -/E R DZ ' ------- ZNG~£O f'/LL U? LIt'.ff HYDr?IL PiPE CHECK V~¥~. VE ttYDRAUL I£ OkE/?,~ TED VZ L VE /( epG,~ ?E ~ O R LO-TOn ?UE //'on~/) GZ,~ OR LD-TO£QUE GATE VALVE £EQUIR£D GATE YA L VE - NOTE' ALL CHANGES I~,UST HAVE WRITTEN APPROVAL BY. THE DISTRICT DRILLING SUPERINTENDENT. " o ~ ST~?,'D,~HD 4 PH£VENTER ~5$£MSLY I ' POSITIV£ CHOKE ADJUST,~SLF CHOKE : .: " : F~.o~, . 8 o ?~ ' S T~ c K · * · · · UOTE: · · · e. e ALL CHANG£S MUST HAVE V,1~ITTEN APPROVAL. DY' THE DISTRICT . DRILLING SUPER;NTENDENT. . - ' .. · $000 p~ ,~ . ./ Art'D.. H.B I. RZVER F£ELO P£ATFo£1~ L J L -t- J£ I I I I I t I. R 14 .W DOLLY D-28 D-3 OG-3 ! I . R ~3 W I I '1 ! TgN I TRADING BAY UNIT E $ P G~'OUP McARTHUR RIVER FIELD STRUCTURE' CONTOUR MAP TOP HEMLOCK FM K,.22 RD .-1'7 6 4 R 11,319 13 W i ARCO McARTHUR .~T. TD 10,255 ~ I0 II 12 15 TD 14,016 I I I K-II TD I 1',094 G-19 ~0 T 29 ~ GRAYLI t0~312 K-4. RD TD II TD 11,772 7 6 ,o ,, G-32 G-4 TO TD 10,16~ II T D 8,580 11 'rD 12,770 9 TD 12,447 IO TD 11,980 TD 13,196 · TD 13,37'4 ,~ G-25 TO 12,~65 11,420 9 io 8 2~. K-7 RD~~'7 TD 14,700 TO 13,500 13 27 ,~ G-9 TD 15,330 T 9 N TD mD I0 i'7 TD I 1)4 40 e¥ TD I 1,4 ~K:) ~o ,.o ,o ... - ~'O'8 . o-.. ,,.. "~" '"' . ,~ ~To~,~o ~ Hi-~t ~ ~ G-12RD-2 : ,, ..,..u o ~./T. ~,,,o~/ ~-~ u-~o ,~/' TRADING BAY UNIT ~ "~~ ~ ~D3~ TO,,~,, G-12RD-2 · ~,~ ~~ "~ o ,~opo Yes No Remarks Item. Appr0v? Da~-a 1. Is the permit fee attached ................... -.. ~ -(1) Fee _~_/~ %Z-Z~.~F 2. Is well to be located in a defined pool ............. '' ' A~ ~ ~. 3. Is a registered survey plat attached ................ 4. Is well located pr .cper distance frcm property line .......... 5. Is well located proper distance frcm other wells .......... 6. Is sufficient undedicated acreage available in this pool ...... 7. Is well to be deviated ....................... C2) Loc. 8. Is operator the only affect, ed party ................ ~l~ 9. Can permit be approved before ten-day wait . . __ · 10. Doos operator have a Ix>nd in force ................. 11, Is a conservation order needed . . . · ......... , ...... 12. Is administrative approval needed ................. 13. Is conductor string provided · · · · · · · · · · · · · · · · · · · · _ · ~15. Will cement tie in-surface and intermediate or prOduction strings 'i'16. Will ~t.' COver all k.hown productive horizons .......... 717. Will surface casing 'protect fresh water zones ...... . . . 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to ~ ~.o o psig 20. Has D~4EM approved Plan of Operation ................ . Additional Roquir~'~nts: 4) Casg. ~~ -(6) Plan Approval, Recc~Taended C o og : Engineering: Revised 4/14/78
