The URL can be used to link to this page

Home My WebLink About178-045 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,April 07,2017 8:46 AM To: Juanita Lovett Cc: Dan Marlowe;samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#316-388/PTD: 178-045/Trading Bay Unit G-08RD Juanita, The AOGCC with withdraw sundry 316-388 as requested below. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Juanita Lovett[mailto:jlovett@hilcorp.comj Sent:Thursday,April 06,2017 9:59 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Dan Marlowe<dmarlowe@hilcorp.com> Subject:Withdraw Sundry#316-388/PTD: 178-045/Trading Bay Unit G-08RD Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to remove the current dual completion,clean out the well to PBTD, re-perforate and run a new gas lifted completion. Regards, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLCY 3800 Centerpoint Drive SC�NNE� �� Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jloyett@hilcorp.com RBDMS ,,L V,":1 - , 2017 • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent Friday,January 27, 2017 1:49 PM To: Juanita Lovett Cc: Dan Marlowe;samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#316-280/PTD: 178-045 -Trading Bay Unit G-08RD Juanita, The AOGCC will withdraw sundry 316-280 as requested. Guy Schwartz Sr. Petroleum Engineer %AHMED JUN 0 52017. AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Juanita Lovett[mailto:jlovett@hilcorp.com] Sent: Friday,January 27,2017 10:48 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Dan Marlowe<dmarlowe@hilcorp.com> Subject:Withdraw Sundry#316-280/PTD: 178-045-Trading Bay Unit G-08RD Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to reperf the G-zone benches 3 and 4 as well as perforate the long string in order to lift Hemlock fluids and produce only through the short string. Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jlovett@hilcorp.com 1 RBDMS FEB 1 0 2017 • • ap1%%y s THE STATE Alaska Sill .lid Gas �St? ,;, � ®f ALAsKiti Conservation C;Immissi®n } z _ y 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Th. Main: 907 279 1433 ALAS Fax 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager r. Hilcorp Alaska, LLC � QCT 3 1 MS 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU G-08RD Permit to Drill Number: 178-045 Sundry Number: 316-388 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 2`t'day of July, 2016. RBDMS U/V15 - 1 2016 0 • RECEIVED STATE OF ALASKA JUL 2 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend 0 Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill 1=IPerforate New Pool LIRe-enterSusp Well I=1Alter Casing ❑ Other. Run New Gil_ Completion 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0% 178-045 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20085-01-00 . 7.If perforating: 8.Wel Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A- Will planned perforations require a spacing exception? Yes ❑ No 0 1 Trading Bay Unit G-08RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 r McArthur River Field/Hemlock and Middle Kenai G Oil Pools . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,750 ' 9,866 - 11,398 ' 9,556• 2,530 psi WA 10,951' Casing Length Size MD TVD Burst Collapse Structural 358' 20" 358' 358' Conductor 589' 16" 589' 588' 2,630 psi 1,020 psi Surface 3,103' 13-3/8" 3,103' 2,786' 3,090 psi 1,540 psi Intermediate 7,820' 9-5/8" 7,820' 6,456' 6,330 psi 3,810 psi Production Liner 4,351' 7" 11,747' 8,963' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,620-11,402 • 8,863-9,560 LS: 3-1/2"&2-3/8" N-80 10,951' SS:3-1/2"&2-7/8"&2-3/8" N-80 10,564' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): , Baker AL-5 Dual Packer,Baker Fl Packer&Otis Ball Valve 10,488'(MD)8,742(TVD);10,875'(MD)9,093(TVD)&SSSV 324'(MD)324'(TVD)LS, 357'(MD)357'(TVD)SS 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/1/2016 Commencing Operations: OIL 0• WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager � Signature `., Phone (907)777-8356 Date 1(Z4' I ( 6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test I=Vtr MechanicalchIntegrity Test ❑ Location Clearance 0 Other: -e 3ODD /a 5 66( f- ! RBDMS 1/-AUG - 1 2016 Post Initial Injection MIT Req'd? Yes 0 No 0 `J�_ f (2•_c Spacing Exception Required? Yes ❑ No V Subsequent Form Required: / d ' `� Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: 7/2,7// eittinpieLates Submit Form and Form 10-403 R�ed� 015 p ro ed p�ication is d fo t of approval.r�;1 / Attachments in Duplicate p7( /,� • • Well Work Prognosis Well: G-08rd Hileorp Alaska,LLC Date: 07/15/2016 Well Name: G-08RD API Number: 50-733-20085-01 Current Status: Gas-Lift Producer Leg: Leg#2 Estimated Start Date: 09/01/2016 Rig: Moncla 404 Reg.Approval 403 Date Reg.Approval Required? Received: Regulatory Contact: Juanita Lovett Permit to Drill Number: 178-045 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell:907-398-9904 Second Call Engineer: Trudi Hallett Office: 907-777-8323 Cell: 907-301-6657 Current Bottom Hole Pressure: -3,642 psi @ 9,449'TVD 0.385 psi/ft,(7.42 ppg)SITP 2011 Maximum Expected BHP: -3,700 psi @ 9,449'TVD 0.385 psi/ft,(7.42 ppg)SITP 2011 Maximum Potential Surface Pressure: -2,530 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary G-08rd is a gas-lift dual string producer completed in the Hemlock and G-zones. This work-over will remove the current dual completion cleanout the well to PBTD re-perforate,and run a new Gas-Lift completion. J Procedure: 1. MIRU over G-08rd. 2. Circulate hydrocarbon from well. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and, 2, O0 psi HIGH. 3 cid py` 4. PU landing joint and make-up to tubing hanger. Circulate any hydrocarbons from the well. 5. Recover dual string completion and cleanout well to PBTD at 11,450' or refusal. 6. PU RIH with RTTS to 10,500' Pressure test casing to-1,500 psi and chart for 30 minutes. µ 11 c s7 7. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. 8. After detonation,circulate perf gas,confirm well is static, POOH. 9. RIH with gas-lift completion. 10. Run Gas-Lift completion with live valves.Space out and land completion. 11. Set Packer/Pressure test completion: • Pressure up and set packer • Test tubing against plug in X nipple to 2500#and chart for 30 minutes. • Test IA to 1,500 psi and chart for 30 minutes(This will pressure up tubing also). 12. Set BPV. NU tree,test same. 13. Schedule SVS testing and• ns. tip, Fra : „ t rtGfi Lc -e-J Attachments: 1. Well Schematic/Current 1,( 7 2 7-t°42. Well Schematic/Proposed "` 3. Wellhead Diagram/Current 4. Wellhead Diagram/Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form ,µ 1110 McArthur River Field,TBU • SCHEMATIC Well:G 08RD PTD: 178-045 As Completed:06/25/1983 Casing Detail CIW Dual Tubing Hangar @ 36.83' A SIZE WT GRADE CONN ID MD TOP MD BTM. J B - - 1 L 20" Surf 358' 16" 75 J-55 Butt 15.124 Surf 589' C C ) 2 13-3/8" 61 J-55 Butt 12.515 Surf 3,103' 47 N-80 Butt 8.681 Surf 81' 9 5/8" 43.5 N-80 Butt 8.775 81' 6,175' D C ) 3 47 N-80 Butt 8.681 6,175' 7,688' Top of 47 P-110 Butt 8.681 7,688' 7,820'(TOW) ) 4 E-line 7" 29 N-80 Butt 6.184 7,396' 11,747' Co1*"�Fish@ Tubing Detail E 0 5 ±5,789' LS 3-1/2" 9.2 N-80 Butt 2.992 0' 7,299' 1.5 2-3/8" 4.6 N-80 Butt 1.995 7,299 10,951' SS 3-1/2" 9.2 N-80 Butt 2.992 Surf. 144' SS 2-7/8" 6.4 N-80 Butt 2.414 144' 7,334' 2-3/8" 4.6 N-80 Butt 1.995 7,334 10,564' F Co -6 NOTE:Window cut from 7,820'to 7,930'.Retainer set @ 7,910. G H I� 7 8 Z Short String Long String III 10 No. Depth(MD) Item No. Depth(MD) Item I r= 11 A 144 2-7/8"x 3-1/2"Crossover 1 324' 3-1/2"Otis Ball Valve J i� 12 B 357 2-7/8"Otis Ball Valve 2 2,587 3-1/2"McMurry-Hughes GLM G K �� 13 C 2,519 2-7/8"GLM 3 4,200 3-1/2"McMurry-Hughes GLM L �= D 4,414 2-7/8"GLM 4 5,584 3-1/2"McMurry-Hughes GLM 14 E 6,008 2-7/8"Camco"XBMG"GLM 5 6,722 3-1/2"McMurry-Hughes GLM M 15 F 7,299 2-7/8"Camco"XBMG"GLM 6 7,299 2-3/8"x 3-1/2"Crossover G 7,335 2-3/8"x 2-7/8"Crossover 7 7,551 2-3/8"Camco"XBMG"GLM N ' 16 H 8,400 2-7/8"McMurray-Hughes GLM 8 8,132 2-3/8"Camco"XBMG"GLM 0I 17 I 9,207 2-7/8"Camco"XBMG"GLM 9 8,626 2-3/8"Camco"XBMG"GLM J 9,645 2-3/8"Otis"RW-4"GLM 10 8,995 2-3/8"Camco"XBMG"GLM P K 10,079 2-3/8"Otis"RW-4"GLM 11 9,340 2-3/8"Camco"XBMG"GLM L 10,301 2-3/8"Otis"RW-4"GLM 12 9,678 2-3/8"Camco"XBMG"GLM 18 M 10,425 2-3/8"Otis"XA"Sleeve 13 10,013 2-3/8"Camco"XBMG"GLM N 10,488 Baker Model"AL-5"Dual 14 10,331 2-3/8"Camco"XBMG"GLM - G• -3 Packer 15 10,455 2-3/8"Otis"XA"Sleeve O 10,563 2-3/8"Otis"XN"Nipple 16 10,488 Baker Model"AL-5"Dual Packer G-4 P 10,564 Bottom of 2-3/8"Coupling 17 10,565 2-3/8"Otis"XA"Sleeve 19 18 10,625 2-7/8"x 2-3/8"Crossover 19 10,626 2-7/8"Blast Joints(Btm 10,744') 20 10,744 2-3/8"x 2-7/8"Crossover 21 10,834 2-3/8"Otis"XA"Sleeve 22 10,873 3-1/2"x 2-3/8"Crossover 20 23 10,874 Baker locator 22. 21 24 10,875 Baker F-1 Packer w/Seal Assy. 23 " 24 (Btm 10,890.89') 25 25 10,891 2-3/8"x 3-1/2"Crossover 26 10,922 2-3/8"Oti"XN"Nipple 27 10,951 Bottom of Mule Shoe i--126 PERFORATIONS 27 = H• B-1 Zone Top MD Btm MD Top TVD Btm TVD Date Status G-3 10,620' 10,645' 8,863' 8,886' N/A Open E-line Fish: - HB-2 G-4 10,668' 10,708' 8,906' 8,943' N/A Open ±5,200'of HB-1 11,058' 11,078' 9,255' 9,273' N/A Open electric line - HB-2 11,102' 11,132' 9,294' 9,321' N/A Open w/30'of 1- = HB-4 HB-4 11,294' 11,324' 9,464' 9,491' N/A Open 1/16"strip HB-4 11,294' 11,324' 9,464' 9,491' 9/9/1994 Open - HB-4 HB-4 11,332' 11,352' 9,498' 9,516' 6/16/1992 Open HB-4 11,332' 11,392' 9,498' 9,551' 9/9/1994 Open HB-4 11,352' 11,402' 9,516' 9,560' 6/15/1992 Open H• B-4 Fish 3 09/17/1994 Fish line rope socket. 1.5"x 5 wt bar. 1.75"x 5 wt bar,1.5"x 5 spang jars,1.5"x 4' hyd jars,2"JDC pulling tool,1.5"braided line cutter bar. 1.5"braided line rope socket,1.5"X over,1.75"x 5'wt bar,1.75"x5'wt bar,1.75"x 5' Fish 2 09/17/1994 spang jars,1.75"x 4'hydraulic jars,1.5"X over,2"JDC pulling tool,1.5"S line rope socket, TD=11,750' ETD=11,398' wire grab Fish 1 09/09/1994 30'of 1.6875"Enerjet gun and 6,750'of wire. Revised 07/05/2016 by DEM • McArthur River Field,TBU 11 • PROPOSED • Well:G-08RD PTD: 178-045 As Completed: Future CIW Dual Tubing Hangar @ 36.83° Casing Detail I I SIZE WT GRADE CONN ID MD TOP MD BTM. 20" Surf 358' 16" 75 J-55 Butt 15.124 Surf 589' 13-3/8" 61 J-55 Butt 12.515 Surf 3,103' 47 N-80 Butt 8.681 Surf 81' 9-5/8" 43.5 N-80 Butt 8.775 81' 6,175' 1 47 N-80 Butt 8.681 6,175' 7,688' 47 P-110 Butt 8.681 7,688' 7,820'(TOW) 7" 29 N-80 Butt 6.184 7,396' 11,747' Tubing Detail 2 3-1/2" I 9.2 I 1-80 I IBT I 2.992 I Surf I ±10,150' NOTE:Window cut from 7,820'to 7,930'.Retainer set @ 7,910. 3 Jewelry Detail Depth Depth ID OD No. (MD) (ND) Description 4 Tubing Hanger 1 ±2,621' ±2,400' GLM 2 ±5,035' ±4,250' GLM 3 ±6,992' ±5,800' GLM L 5 1 .. 4 ±8,502' ±7,000' GLM 5 ±9,494' ±7,850' GLM 6 ±10,070' ±8,367' GLM-Orifice 6 - 7 ±10,100' ±8,394' Packer _ 8 ±10,130' ±8,421' X-Nipple 7 9 ±10,150' ±8,438' WLEG 8 aMit 9 " . PERFORATIONS Zone Top MD atm MO Top ND Btm ND Date Status ±10,291' ±10,300' ±8,564' ±8,572' Future Proposed - G61 ±10,385' ±10,399' ±8,649' ±8,662' Future Proposed GG GG1 ±10,413' ±10,429' ±8,674' ±8,689' Future Proposed GG1 G-01 ±10,485' ±10,505' ±8,740' ±8,758' Future Proposed G01-02 ±10,530' ±10,549' ±8,781' ±8,798' Future Proposed G-01 6-03 ±10,612' ±10,647' ±8,855' ±8,887' Future Proposed G01 02 G-03 10,620' 10,645' 8,863' 8,886' N/A Open G-04 ±10,655' ±10,707' ±8,895' ±8,942' Future Proposed = G-3 G-04 10,668' 10,708' 8,906' 8,943' N/A Open G 4 G-04 ±10,716' ±10,724' ±8,950' ±8,957' Future Proposed G-05 ±10,763' ±10,773' ±8,992' ±9,001' Future Proposed G-5 H-2 ±11,053' ±11,075' ±9,251' ±9,270' Future Proposed H-1 11,058' 11,078' 9,255' 9,273' N/A Open H-2 ±11,093' ±11,203' ±9,286' ±9,384' Future Proposed H-2 11,102' 11,132' 9,294' 9,321' N/A Open H-3 ±11,211' ±11,220' ±9,391' ±9,399' Future Proposed H-3 ±11,229' ±11,254' ±9,407' ±9,429' Future Proposed H-1 H-3 ±11,267' ±11,321' ±9,440' ±9,488' Future Proposed _ H-4 11,294' 11,324' 9,464' 9,491' N/A Open H-4 11,294' 11,324' 9,464' 9,491' 9/9/1994 Open H-2 H-4 ±11,328' ±11,403' ±9,494' ±9,561' Future Proposed H-3 H-4 11,332' 11,352' 9,498' 9,516' 6/16/1992 Open H-4 11,332' 11,392' 9,498' 9,551' 9/9/1994 Open H-4 H-4 11,352' 11,402' 9,516' 9,560' 6/15/1992 Open ME H-5 ±11,423' ±11,453' ±9,579' ±9,605' Future Proposed - H 5 H-5 ±11,462' ±11,503' ±9,613' ±9,649' Future Proposed = H-5 ±11,515' ±11,529' ±9,660' ±9,672' Future Proposed H-5 ±11,542' ±11,552' ±9,684' ±9,692' Future Proposed H-6 H-6 ±11,563' ±11,581' ±9,702' ±9,718' Future Proposed H-6 ±11,608' ±11,639' ±9,742' ±9,769' Future Proposed TD=11,750' ETD=11,398' Revised 2016-07-251LL • • II Grayling Platform G-O8RD Current 07/24/2016 Hilrurh:tla*ku.lit: Grayling G-08rd Tubing hanger, dual,CIW- 13 3/8 X 9 5/8 X 3 1/2 X DCB, 11 5M X 3'A EUE 8rd lift 3 1/2 X 3'A IBT bottom,w/3"type _ H BPV profile, 1/8 non cont ' control line ports in hangers ®0. •/ / III II Mr Tree assy, dual block, CIW-F, 115MX31/85MX31/8 5M, prepped on rerP:114 5 3/64 center, 3" CIW seal Cr" pockets,Y2 npt control line O •t'tg exits —641; ; rt; , 6 rl►=,.7 n\ (111 am 44) t- t -ISN O • N: �e Tubing head,CIW-DCB, 111 Valve, FMC 120, 2 1/16 5M 135/83MX115M,w/2- „ , FE' HWO,AA 2 1/16 5M SSO,X-bottom ' -ie prep OMROC)0:4_011'1' III-i•=' _ c4iiiir t, alt ■I N_ Casing head, Shaffer KD, 135/83MX UPI 1r.. 13 3/8 SOW,w/2-2” , _. ® 2"LP CIW ball valve LPO, •I VIM( 0 ,.. 11-1 1 • • H Grayling Platform G-08RD Proposed 07/24/2016 fiilrnrp ahe,+h:1.1,15. Grayling Tubing hanger,CIW-DCB- G-08rd FBB,11 X 3 Y.EUE 8rd lift X 13 3/8 X 9 5/8 X 3 1/2 susp,w/3"type H BPV,1/2 npt continuous control line, 6.25"extended neck prep Tree cap,Bowen,3 1/8 SM FE X 3"Bowen Quick Union 0 , Valve,Swab,WKM-M, i 3 1/8 5M FE,HWO, ., 01 DD trim '„"- 4 Valve,Wing,WKM-M, ," 3 1/8 5M FE,w/15" calm OMNI operator,DD trim Cross,stdd,3 1/8 5M X i I ri +' 31/8SM ! OQ i s ' iMINIM miming Valve,Upper Master, WKM-M,3 1/8 5M FE,HWO, L .' 1 DD trim 11111017171 MI �." 1 au Valve,Master, 04. r� WKM-M,3 1/8 5M FE,HWO, ,j �.. DD trim �� v_ Tubing head,CIW-DCB, _u30I , 1 iv.. 13 5/8 3M X 11 SM,w/2- �11 M. Si Valve,WKM-M,2 1/16 2 1/16 5M SSO,X-bottom 5M FE,HWO,AA prep II ``1� I. �[a joIi '' o c o e e 1 lit 111 a 1.1 _ Casing head, Shaffer KD, III ± III 135/83MX 13 3/8 SOW,w/2-2" LPO, MIi ��ioni c). ..i...i•1"; • • Grayling Platform 2016 BOP Stack Moncla 05/13/2016 Hihnip:Uaokm.1.1R. 111 IIIifl(II111 4.54' �O O 2 7/8-5 5 Shaffer SL variables 2.83' 135/85M Blinds 00 O � Choke and Kill valves 2 1/16 5M 2.26' ;OL4 ;'r ! Mud C• J! , • i;M 41/165 � Iti'I�I IilliI al 1W 141111111111111 III Ifi 111 1111 a�ser 135/85M FE X 135/85M FE 14.20' lit- - f hart Ili Iii il! I i iii Spacer spool 135/B SM FEX115M - 2.75' 11.111 111 Al Ili tit lit • • • C) DI ... r ? A 0 C C o r C oN m Z 1-1 m0 — 1 7j 0 D 0 Z J m r r 0ZO ° � n O m X —1— z 0g —il r� ❑ C r N OP I I I CO m0-13 Z o Y z cn • D Z 0 H m M n � - I 111'111 - ,ii iii m S A 6-5 m I,// pm O m Q J II 0 co S D . i c O Z ? ' (,1 0 13 C m mr m� 13E Lam: I•-.0---1Z Z m i oo - v CO N II I 4k I -. i 3 On = � ll?' 0_ 0 o- m n m E c s 9 ? S 9 S S S S S S ^ x c c c c c • v o 0 0 0 0 0 0 0 0 0 o p s 3 3 3 3 3 x m m m m r n m m m m m m ,o m m 0 < g ~ v -0 13 v n O o m w m a3+ a3+ d F 3 d d m m ^' EEFEE m - - n n . m n D N O O O O O m 0 0 0 0 0 0 0 0 0 0 o a a n a a a a a a a a n n no_ 0 - Lo CO �1 Q1 V, A W N N Ln A W N N n n n n n n n n n - 'o v v v v _. 0 w V m U,, a w NI - ,o... 3 A 3 N 3 0 O n n O n n O n O n O n o O n O O n O n 0 0 • • 0 Zl n C I- > Ii co 0 Z -n co AJ .1- * 7J C 2 Z D O ) m 1-rr CD - -<N Z -0 * m * CDDIt < r ; Q = OZ Z ci o OP' cc m0 D —IN Z 0 Z z C r- >D z 0 m l< cn —1m _g m n � 212 ii,i„, \� or o m O < 7J A n <A m ii oz :- =w 00 A m7J 1_...._: 1■ r 2z mn 7, - 0 00 - J CD Ni M. 3 r T b a S a Oll i:7 0 m o_v a a m 3c g9n9+ nnnnnn nx2cE V vvvv < S S S S S S S S - = C C C C C b Fri 0 0 0 0 0 0 0 0 r z i - 3 3 3 3 3 < m io io m FT m m m m io r d > > v v � v v � nn<i ns3333333333 � ;+ �' d d v m o3+ < c 0 m `D 0 0 > 0 3 CD 0 0 0 0 0 0 0 0 0 0 0- O O O O O a n n n n n n n n n O a n O_ a s f+ w co J al N A w N f+ 0 N A W N t+ 0 n n n n n n n n n E. V -0 v v v 333333 crlNJ A W NJ 0 V N O n n O n n O n O n O n O O n 0 0 O n O n O n '; 0 0 • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,IAA: Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) Moncla Rig 404 BOP Test Procedure Hilcorp Alneka,�.�.c Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close ft valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open 15t valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^ 1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,i.�.c Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. 0 0 Cl) 0 2 f 0 0 / Cr. -. 7 [ 0o Q co Z ° A m '< f C Fr _ CA 'V -Tico \ / 0) s › CO ■ x 0 C 0 3 las /m 13 p CD 0 < f -0 0 _ s -a 0 � _ f \ a 70 § a CD (0 ¢ \ u, 0. XI = ■ c @ CO E/ o_ § CO �. _Q O. § k g — 0 0 ( 7 / X" 3 \ CD 2 = 4 2 CD a > m f c QE / / / _ w * � m / k \ o ■ 13 / 0- .:-.0 CD < m 0Q. / • 0 •M » / k -<2C vi 70 // 0 0 � R * 3 - go ID2m § mo # M % w %' § R / § _ / a /�� 7k a E § Ca D $ / 2 I k \ / m50 0. / 3 D § �2 > yB• 0 o 0 q \ § - 0 CO cp \ am * » OO. ) 3 CD ■ Z £ COQ iv OF Tit • • ��.\ Iyyy • THE STATE Alaska Oil and Gas 7� OfA L Conservation Commission {2 = =—l 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. GolisscowSEP 2 9 2.016 Operations Manager Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU G-08RD Permit to Drill Number: 178-045 Sundry Number: 316-280 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A1944-4.44.. Cath P. Foerster Chair DATED this 2,--514d—ay of May, 2016. RBDMS I,V- MAY 3 1 2016 • • -ED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MN( 1 8 2016 APPLICATION FOR SUNDRY APPROVALS 5/zS 20 AAC 25.280 AO 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 - 178-045 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic CIService ❑ 6.API Number. Anchorage,AK 99503 50-733-20085-01-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A • Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit G-08RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 • McArthur River Field/Hemlock and Middle Kenai G Oil Pods . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,750 - 9,866 ' ` 11,398 . 9,556 2,814 psi N/A —10,951' Casing Length Size MD TVD Burst Collapse Structural 358' 20" 358' 358' Conductor 589' 16" 589' 588' 2,630 psi 1,020 psi Surface 3,103' 13-3/8" 3,103' 2,786' 3,090 psi 1,540 psi Intermediate 7,820' 9-5/8" 7,820' 6,456' 6,330 psi 3,810 psi Production Liner 4,351' 7" 11,747' 8,963' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,620-11,402 - 8,863-9,560 LS: 3-1/2"&2-3/8" N-80 10,951' SS:3-1/2"&2-7/8"&2-3/8" N-80 10,564' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(It): Baker AL-5 Dual Packer,Baker Fl Packer&Otis Ball Valve % 10,488'(MD)8,742(ND);10,875'(MD)9,093(TVD)&SSSV 324'(MD)324'(TVD)LS, 357'(MD)357'(ND)SS • 12.Attachments: Proposal Summary El Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/1/2016 Commencing Operations: OIL El • WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallett@hilcorD.com Printed Name Stan W.GolisTitle Operations Manager Signature 5L 4`-) r/`•D Phone (907)777-8356 Date 51 t a( 1 L COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number '' \CQ— 250 Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS l MAY 3 1 2016 Spacing Exception Required? Yes El No UO Subsequent Form Required: /6 l D APPROVED BY Approved byOti611 P COMMISSIONER THE COMMISSION Q Date: 5..a5-/4 �t� '9 0 Rpfte +NtAlblid "1L� S Atttach SubmnFormane Form 10-403 vised 11/2015 for 12 mons from the date of approval. D_ Attachments in Duplicate • •11 • Well Work Prognosis Well: G-08RD Date: 05/18/2016 Hi!carp Alaska,LLC Well Name: G-08RD API Number: 50-733-20085-01 Current Status: Gas-Lift Producer Leg: Leg#2 Estimated Start Date: 06/01/2016 Rig: N/A Reg.Approval 403 Date Reg.Approval Received: Required? Regulatory Contact: Juanita Lovett Permit to Drill Number: 178-045 First Call Engineer: Dan Marlowe Office:907-283-1329 Cell: 907-398-9904 Second Call Engineer: Trudi Hallett Office:907-777-8323 Cell:907-301-6657 Current Bottom Hole Pressure: -3,700 psi @ 8,863'TVD (10,620'MD) Based on surrounding well data Maximum Expected BHP: -3,700 psi @ 8,863'TVD (10,620'MD) Maximum Potential Surface Pressure: -2,814 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The G-08RD was initially re-drilled and completed in 1978. This well is currently completed in both the Hemlock and G-Zone benches as a dual string gas-lift producer.The well was shut-in from mid-2002 until October of 2015 when Hilcorp brought the long string(Hemlock only) back online.The short string is shut-in. The rate is limited due to the restriction in the long string because of E-line tools left in the tbg. The below procedure will reperf the G-Zone benches 3 and 4 as well erforat he long string in able to lift Hemlock fluids and produce only thru the short string. / ,gt 1( G- s c' a/C4.L`) Coln q � -. Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 2. RU e-line guns and perforate per program. Record tubing pressures before and after perforating run. 3. RD E-line. �-�-- 4. Turn well over to production. Attachments: 1. Current Well Schematic 7 2. Proposed Well Schematic �.6` 41/6jvi"51-9 � eti C l McArthur River Field,TBU II 0 SCHEMATIC • Well: G-08RD ,tip"wameke,LLC As Completed: 8/19/1978 • Casing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. 20" Surf. 358' CIW Dual Tubing Hangar @ 36.83' 16" 75 J-55 Butt 15.124 Surf. 589' B hi=' 13-3/8" 61 1-55 Butt 12.515 Surf 3,103' 1 9-5/8" 43.5 N-80 Butt 8.775 Surf 7,820' �� 7" 29 N-80 Butt 6.184 7,396' 11,747' c' 2 ; ,�� Tubing Detail D' . 3 1 LS 3-1/2" 9.2 N-80 Butt 2.992 0' 7,299' LS 2-3/8" 4.6 N-80 Butt 1.995 7,299 10,951' Top of SS 3-1/2" 9.2 N-80 Butt 2.992 Surf. 144' ' 4 E-line SS 2-7/8" 6.4 N-80 Butt 2.414 144' 7,334' Fish@ 2-3/8" 4.6 N-80 Butt 1.995 7,334 10,564' E mo ' 5 ±5,789' NOTE:Window cut from 7,820'to 7,930'.Retainer set @ 7,910. Short String Long String F , 6 No. Depth(MD) Item No. Depth(MD) Item G7 A 144 2-7/8"x 3-1/2"Crossover 1 . 324' 3-1/2"Otis Ball Valve 8 B 357 • 2-7/8"Otis Ball Valve 2 2,587 3-1/2"MCMurry-Hughes GLM ..tr 2 :...r, H' '- 9 C 2,519 2-7/8"GLM 3 4,200 3-1/2"McMurry-Hughes GLM aT !. 10 D 4,414 2-7/8"GLM 4 5,584 3-1/2"McMurry-Hughes GLM 'W '. 11 E 6,008 2-7/8"Camco"XBMG"GLM 5 6,722 3-1/2"McMurry-Hughes GLM 12 F 7,299 2-7/8"Camco"XBMG"GLM 6 7,299 2-3/8"x 3-1/2"Crossover III in K nom '== 13 G 7,335 2-3/8"x 2-7/8"Crossover 7 7,551 2-3/8"Camco"XBMG"GLM L 'MI= -IM 14 H 8,400 2-7/8"McMurray-Hughes GLM 8 8,132 2-3/8"Camco"XBMG"GLM III M �� 15 I 9,207 2-7/8"Camco"XBMG"GLM 9 8,626 2-3/8"Camco"XBMG"GLM J 9,645 2-3/8"Otis"RW-4"GLM 10 8,995 2-3/8"Camco"XBMG"GLM NII 16 K 10,079 2-3/8"Otis'RW-4" GLM 11 9,340 2-3/8"Camco"XBMG"GLM 0 17 L 10,301 2-3/8"Otis"RW-4"GLM 12 9,678 2-3/8"Camco"XBMG"GLM 111 M 10,425 2-3/8"Otis"XA"Sleeve 13 10,013 2-3/8"Camco"XBMG"GLM P N 10,488 Baker Model"AL-5"Dual 14 10,331 2-3/8"Camco"XBMG"GLM Packer 15 10,455 2-3/8"Otis"XA"Sleeve -- 18 0 10,563 2-3/8"Otis"XN"Nipple 16 10,488 Baker Model"AL-5"Dual Packer 17 10,565 2-3/8"Otis"XA"Sleeve G-3 18 10,625 2-7/8"x 2-3/8"Crossover G-4 19 10,626 2-7/8"Blast Joints(Btm 10,744') 20 10,744 2-3/8"x 2-7/8"Crossover 19 21 10,834 2-3/8"Otis"XA"Sleeve 22 10,873 3-1/2"x 2-3/8"Crossover 23 10,874 Baker locator Baker F-1 Packer w/Seal Assy. 20 24 10,875 (Btm 10,890.89') 22 31 Il21 25 10,891 2-3/8"x 3-1/2"Crossover 24 26 10,922 2-3/8"Oti"XN"Nipple 25 27 10,951 Bottom of Mule Shoe 26 PERFORATIONS Ili ini Zone Top MD Btm MD Top TVD Btm ND Date Status 27 - HB-1 �I G-3 10,620' 10,645' 8,863' 8,886' N/A Open / = HB 2 G-4 10,668' 10,708' 8,906' 8,943' N/A Open E-line Fish: HB-1 11,058' 11,078' 9,255' 9,273' N/A Open ±5,200'of electric line - HB-2 11,102' 11,132' 9,294' 9,321' N/A Open w/30'of 1- - HB-4 HB-4 11,294' 11,324' 9,464' 9,491' N/A Open 1/16"strip HB-4 11,294' 11,324' 9,464' 9,491' 9/9/1994 Open HB-4 HB-4 11,332' 11,352' 9,498' 9,516' 6/16/1992 Open H8-4 11,332' 11,392' 9,498' 9,551' 9/9/1994 Open HB 4 HB-4 11,352' 11,402' 9,516' 9,560' 6/15/1992 Open ............... TD=11,750' ETD=11,398' 1 Revised 8/10/2012 by TDF McArthur River Field,TBU PROPOSED Well: G-08RD Hileurp Alaska,LLC Completed: 8/19/1978 Casing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. 20" Surf. 358' CIW Dual Tubing Hangar @ 36.83' 16" 75 J-55 Butt 15.124 Surf. 589' J i B ■R, I 13-3/8" 61 J-55 Butt 12.515 Surf 3,103' 1 L 9-5/8" 43.5 N-80 Butt 8.775 Surf 7,820' 7" 29 N-80 Butt 6.184 7,396' 11,747' 2 Tubing Detail D 3 LS 3-1/2" 9.2 N-80 Butt 2.992 0' 7,299' LS 2-3/8" 4.6 N-80 Butt 1.995 7,299 10,951' Top of SS 3-1/2" 9.2 N-80 Butt 2.992 Surf. 144' ' 4 E-line SS 2-7/8" 6.4 N-80 Butt 2.414 144' 7,334' E Fish@ 2-3/8" 4.6 N-80 Butt 1.995 7,334 10,564' 5 +5,789' NOTE:Window cut from 7,820'to 7,930'.Retainer set @ 7,910. Ir ` is : 1 Short String Long String F , - 6 No. Depth(MD) Item No. Depth(MD) Item G - i� 7 y A 144 2-7/8"x 3-1/2"Crossover 1 324' 3-1/2"Otis Ball Valve -- 8 B 357 2-7/8"Otis Ball Valve 2 2,587 3-1/2"McMurry-Hughes GLM II H'� -- 9 C 2,519 2-7/8"GLM 3 4,200 3-1/2"McMurry-Hughes GLM '!m 10 D 4,414 2-7/8"GLM 4 5,584 3-1/2"McMurry-Hughes GLM I 'mini 'm.m 11 E 6,008 2-7/8"Camco"XBMG"GLM 5 6,722 3-1/2"McMurry-Hughes GLM J ' i 12 F 7,299 2-7/8"Camco"XBMG"GLM 6 7,299 2-3/8"x 3-1/2"Crossover K ,N .mm 13 G 7,335 2-3/8"x 2-7/8"Crossover 7 7,551 2-3/8"Camco"XBMG"GLM L 'im 14 H 8,400 2-7/8"McMurray-Hughes GLM 8 8,132 2-3/8"Camco"XBMG"GLM I 9,207 2-7/8"Camco"XBMG"GLM 9 8,626 2-3/8"Camco"XBMG"GLM M o Jo 15 J 9,645 2-3/8"Otis"RW-4"GLM 10 8,995 2-3/8"Camco"XBMG"GLM N i- 16 K 10,079 2-3/8"Otis"RW-4"GLM 11 9,340 2-3/8"Camco"XBMG"GLM L 10,301 2-3/8"Otis"RW-4"GLM 12 9,678 2-3/8"Camco"XBMG"GLM 0 w•a M.a. 17 M 10,425 2-3/8"Otis"XA"Sleeve 13 10,013 2-3/8"Camco"XBMG"GLM N 10,488 Baker Model"AL-5"Dual 14 10,331 2-3/8"Camco"XBMG"GLM Packer 15 10,455 2-3/8"Otis"XA"Sleeve -- 18 0 10,563 2-3/8"Otis"XN"Nipple 16 10,488 Baker Model"AL-5"Dual Packer rt G 3 17 10,565 2-3/8"Otis"XA"Sleeve f 18 10,625 2-7/8"x 2-3/8"Crossover G-4 19 10,626 2-7/8"Blast Joints(Btm 10,744') `.11r19 - 20 10,744 2-3/8"x 2-7/8"Crossover I. 21 10,834 2-3/8"Otis"XA"Sleeve S+r•� 22 10,873 10,874 3-1/2"x 2-3/8"Crossover fff lJ,�i 23 Baker locator „v✓]� \J 24 10,875 Baker F-1 Packer w/Seal Assy. U 20 r��21 (Btm 10,890.89') ff' - C(i22-! 25 10,891 2-3/8"x 3-1/2"Crossover 24 26 10,922 2-3/8"Oti"XN"Nipple - . 25 27 10,951 Bottom of Mule Shoe .®26 PERFORATIONS 'IZone Top MD Btm MD Top ND Btm ND Date Status 27 s HB-1 �I - G-3 ±10,615' ±10,644' ±8,858' ±8,885' Future / = HB-2 G 3 10,620' 10,645' 8,863' 8,886' N/A Open E-line Fish: G-4 ±10,658' ±10,705' ±8,897' ±8,940' Future ±5,200'of G-4 10,668' 10,708' 8,906' 8,943' N/A Open electric line -- w/30'of 1- HB-4 HB-1 11,058' 11,078' 9,255' 9,273' N/A Open 1/16"strip HB-2 11,102' 11,132' 9,294' 9,321' N/A Open HB-4 HB-4 11,294' 11,324' 9,464' 9,491' N/A Open HB-4 11,294' 11,324' 9,464' 9,491' 9/9/1994 Open HB 4 HB-4 11,332' 11,352' 9,498' 9,516' 6/16/1992 Open HB-4 11,332' 11,392' 9,498' 9,551' 9/9/1994 Open HB-4 11,352' 11,402' 9,516' 9,560' 6/15/1992 Open TD=11,750' ETD=11,398' Revised 5/18/16 BYJLL -1 ,�V 0 4kS Dale A. Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 Operations Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 /�UCa V 21109 Cathy Foerster Commissioner lei.-A'A oil & 11ars Cans„ Crait migi;inn Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, �) -F, 1 � ax, %ANNED Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Collapsed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore in ection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase 1 Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug-9parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21 A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec-0pNoknown wn damage no flow Possible shallow as or as storage 2011-2014 Monopod A-10 1670760 A r-8ed casingProducingCoal Phase I Abandon abandon at end of platform Life Monopod A-23 1720200 Jun-8ed casingProducingCoal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 damage Water production due to WF breakthrough Phase I Abandon abandon at end of latform life ASK. 011L AND GALS CONSERVATION C®MUSS101V June 22, 2009 `1 Y_o4S SARAH PALIN, GOVERNOR t` 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 SCONE,, Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(a)alaska. Yov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 _I Union Oil Company of California 167-077 _ Granite Pt St 18742 16 _ Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 _ _ Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 _ Union Oil Company of California 182-083 Trading Bay Unit D-40RD _ Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 Trading Bay Unit D-06RD Union Oil Company of California 188-028 Trading Bay Unit G-34RD _ Union Oil Company of California 168-038 Trading Bay Unit K-06RD _ Union Oil Company of California 169-066 Trading Bay Unit K-09 _ Union Oil Company of California 179-016 _ Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 _ MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 _ MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 _ Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 _ Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 _ Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 _ Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 ~KA OIL AND GAS CONSERVA~ION COPIPlXSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 5, 2001 Dwight Johnson, Superintendent Chris Meyers, Superintendent UNOCAL Field Superintendents 260 Caviar Street Kenai, Alaska 99611 RE: No-Flow Verification TBU Well G-25, PTD 176-037 TBU Well G-8RD (L), PTD 178-045 Gentlemen: On April 26, 2001 AOGCC Petroleum Inspector John Spaulding witnessed a "no-flow test" on UNOCAL's Grayling Platform. Wells G-25 and the long string of G-8RD were tested. Mr. Spaulding arrived on Grayling Platform and found the wells shut in and depressurized as requested. Over the course of the three (3) hour witnessed period, test performance of TBU Well G-25, PTD 176-037 and TBU Well G-8RD (L), PTD 178- 045 demonstrated that the wells were incapable of unassisted flow of hydrocarbons to the surface. Therefore, these wells need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve ("SSSV") system. However, these wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason any of the wells become capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board Grayling. Sincerely Sr. Petroleum Engineer TEM:\jjc e e . ".7cg-04S State of A'aSkalf-tt ~1ì . Alaska on and Gas Conservation Commission MEMORANDUM TO: Julie Heusser, Commissioner DATE: May 26, 2001 TBRU: Tom Maunder, P. I. Supervisor SUBJECT: No Flows Unocall TBU Grayling Platform Wens G-25 &G8.L FROM: John H Spaulding, Petroleum Inspector April 26. 2001: I traveled to Unocal's Grayling Platform to witness the No Flow tests on well G-25 and GaL. Prior to my arrival the gas lift was shut in and the wells de-pressured as requested. An Armor flow meter was attached to the flowtine to measure gas flow. The flow meter ean measure from 100 standard cubic feet per hour (seth) to 2000 seth. A 5 gal bucket was used for monitoring and measuring fluids. G-25 Initial reading:1:30pm Tubing: 0 positive Inner annulus: 0 Flow: Positive - not measurable liquids: None ~ Initial Reading: 1 :30 pm Tubing: 0 positive Inner annulus: 0 Flow: positive - not measurable liquids: None 2:30 pm Tubing: 0 positive Inner Annulus: 0 Flow: 0 Positive liquids: 0 2:30 pm Tubing: 0 positive Inner annulus: 0 Flow: 0 positive liquids: 0 3:30 pm Tubing: 0 Positive Inner Annulus: 0 Flow: 0 Positive Liquids: 0 3:30 pm Tubing: 0 positive Inner annulus: 0 Flow: 0 positive Liquids: 0 4:30 pm Tubing: 0 Positive 4:30 pm Tubing: 0 positive e e Inner annulus: 0 Flow: 0 positive Liquids: 0 Inner annulus: 0 Flow: 0 positve Liquids: 0 SUMMARY: , recommend wells G-25 and G9L for No-flow status based on the observed test. Attachment: None Non Confidential Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 March 14, 1995 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: ~ ':~" q~'~ On September 9, 1994 the following intervals were perforated in well G-8RD (API 50-733-20085-01) in the McArthur River Field: BENCH TOP (MD) BOTTOM (MD) HB4 11,294 11,324 30 HB4 11,332 11,392 60 TOTAL 90 FEET Sincerely, RECEIVED APR 20 1995 Alaska Oil & Gas Cons. Commission Anchora~ '~ STATE OF ALASKA ALA"""~A OIL AND GAS CONSERVATION '~MMISSION REPOt £ OF SUNDRY WELL Oi-'ER^TIONS 1. Operations performed: Operation shutdown Pull tubing __ Alter casing__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1874' N, 1382' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 3688' S, 3902' E of Surface Location At effective depth 4163' S, 4131' E of Surface Location At total depth 4163' S, 4131' E of Surface Location Stimulate __ Plugging __ Perforate X_ Repair well __ Pull tubing __ Other__ 5. Type of Well: Development X_ Exploratory __ Strafigraphic m Service __ ORIGINAL 6. Datum elevation (DF or KB) KB: 103' 7. Unit or Property name Trading Bay Unit 8. Well number G-j8RD feet 9~:~e..r~3u mbe r/approval number '~94-232 10. APl number 50 -733-20085-01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical 11,747 feet Plugs (measured) 9854 feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured measured 11,747 feet Junk (measured) true vertical 9854 feet Length Size Cemented Measured depth True vertical depth 358' 20" Driven 358' 358' 589' 16" 1200 sx 589' 589' 3103' 13-3/8" 2300 sx 3103' 2774' 7820' 9-5/8" 3300 sx 7820' 6444' 4351' 7" 830 sx 7396'-11,747' 6115'-9854' 10620-10645,10668-10708,11058-11078,11102-11132,11294-11324,11332-11402 true vertical 8844-8869,8912-8952,9145-9165,9294-9324,9463-9493,9501-9571 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. LS: 3-1/2", N-80 (iD 7299'; 2-3/8", N-80 @ 10,951' SS: 3-1/2", N-80 @ 144'; 2-7/8", N-80 @ 7334' Baker AL-S dual pkr. @ 10,488'; Baker F1 pkr. @ 10,875'; SSSV @ 324'(LS) RECEIVED Intervals treated (measured) APR 2 0 199,5 Treatment description including volumes used and final pressure -~Ka uti & Gas Cons. C0fflll~ssJ0n Representative Daily Average Production or Injection Data Anch0ra, ~, Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 164 156 1488 1350 120 242/'''' 129 1880 1400 200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil X_ Gas __ Suspended __ Service 117. I herel~y certify that tee foregoing is true.a~ correct to the best of my knowledge. Form 10-4~ Rev 06/15/~ SUBMIT IN DUPLICATE 1. Type of reouest: STATE OF ALASKA ALASK~---")IL AND GAS CONSERVATION CC-"-'MISSION · APPLIC, . 'ION FOR SUNDRY Al' , ROVALS Abandon ~ Uuspend ~ Operations shutdown ~ Re-enter suspended weil~ Alter casing__ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate X_ Other__ 2. Name of Operator Unocal 3. Address . 12. P.O. Box 196247 Anchorage, Alaska 99519-6247 Location of well at surface 1874' N, 1382' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 3688' S, 3902' E of surface location At effective depth 4163' S, 4131' E of surface location At total depth 4163' S, 4131' E of surface location Present well condition summary Total depth: measured 11747 feet true vertical 9854 feet 5. Type of Well: Devehuprnent X_ Exploratory __ Strafigraphic __ RECEIVED ~',J;:s¥~a Oil & O~ts Cons. Commiss Anchor%~ Plugs (measur~ 6. Datum elevation (DF or KB) KB: 99' 7. Unit or Property name Trading Bay Unit 8. Well number G-8RD 9. Permit number 10. APl number 50-733-20085-01 i~lq. Field/Pool McArthur River/Hemlock Effective depth: measured 11747 feet true vertical 9854 feet Junk (measured) feet Casing Length Structural 358' Conductor 589' Surface 3103' Intermediate 7820' Production Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 20" Driven 358' 358' 16' 1200 sx 589' 589' 13-3/8' 2300 sx 3103' 2774' 9-5/8' 3300 sx 7820' 6444' 4351' 7' 830 sx 7396'-11747' 6115'-9854' 10620-10645,10668-10708,11058-11078,11102-11132,11294-11324,11332-11402 true vertical 8844-8869, 8912-8952, 9145-9165, 9294-9324, 9463-9493, 9501-9571 Tubing (size, grade, and measured depth) LS: 3-1/2', N-80 @ 7299'; 2-3/8", N-80 @ 10951' SS: 3-1/2', N-80 @ 144'; 2-7/8' N-80 @ 7334' Packers and SSSV (type and measured depth) Baker AL-S dual pkr. @ 10488'; Baker F1 pkr. @ 10875'; SSSV @ 324' (LS) & 13. Attachments Description summary of proposal X_ Detailed operations prograrn~__ BOP sketch __ Questions? Call Hal Martin @ 263-7675 or Ralph Holman @ 263-7838 14. Estimated date for commencing operation ~15. Status of well classirK~ation as: September 6, 1994 r 16. If proposal was verbally approved Oil X_ Gas __ Name of approver Date approved Service 17. I hereby ce[tify that t.b,e_foreg,oi0g ~d correct to the best of my knowledge. FOR COMMISSION USE ONLY Suspended__ Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test_ Location clearance ~ Mechanical Integrity Test__ Subsequent form required 10- 4 ~/-/ Approved by the order of the Commission · Jng~nal Signea By Oavid W. Johnston Form 10-403 Rev 06/15/88 {Approval No. _ ~°~~ oo¢ I ~ ,--,,'- ,2. ~ ,<., . ~.~'"~mmissioner Date SUBMIT IN TRIPLICA'IXE Unocal North American~..~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 August 19, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well G-SRD (API# 50-733-20085-O1) on the Grayling platform. BENCH TOP (MD) BOTTOM (MD) FEET HB1 11,058 11,078 20 HB4 11,294 11,324 30 HB4 11,332 11,402 70 TOTAL 120 RECEIVED August 19, 1994 Grayling Platform, Well G-8RD Perforating Procedur0 1. Hold safety meeting. 2. Rig up electric line unit. . Pressure test lubricator to 2500 psi for five minutes. Note: A pump-in sub with a valve is required. 4. Shut down all welding and radio transmissions. . Run in hole and perforate intervals as instructed by Unocal wimess. (When gun is 200' below surface, welding and radio transmissions may resume.) . Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL HB1 11,058-11,078 20 HB4 11,294-11,324 30 HB4 11,332-11,402 70 FEET TOTAL: 120 RECEIVED a!~,~ska ()ii &. 6as Cons. Commission Anchon, Unoc.~i Nor'tt~ Ame Oil & Gas ~ivision P 0. ~ox ~ 902~7 Anc2~rage. Alaska 99519-024T Te~eonone ~90~ 275-7800 A~s~a Region April 16, 1990 Alaska Oil & Gas Conservation Commission 300! Porcupine Dr. Anchorage, A2f 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of t~e "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 "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 21 2,279.28 1804 2,502,347.99 212,277.68 G-36 1800 2,502,345.80 212,273.75 G-34 & RD 179'8 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 =151°36' 48.042" 2,502,380.80 212,197.90 1831 13 14 15 16 17 18 19 20 21 22 23 24 LEG #l: 2 · LAT = 60o50' 23.575" LONG =151°36' 47..505" ' 2,502,374.34 212,196.66 G-14A 1825 2,502,376.65 212,192.79 G-19 1827 2,502,380.90 212,191.32 G-13 1831 2,502,385.11 212,192.92 G-15 1835 2,502,387.30 212,196.85 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-10 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 C'ompressors) LEG #2: LAT = 60o50' 23. 313" LONG =151°36' 45.982" 2,502,427. lO 212,301.20 1880 37 38 39 4O 41 42 43 44 45 46 47 48 2,502,421.45 212,297.82 G-12, RD & 2 1874 2,502,424.94 212,294.98 G-31 1878 2. 502,429.4 5 212,295.05 G-4 1882 2,502,432.85 212,297.99 G-1 1886 2,502,433.57 212,302.44 G-9 1886 2,502,431.26 212,306.31 G-18 1884 2. 502,427.00 212,307.78 G-14 1880 2,502,422.80 212,306.18 .................. G.-30 ........... 1876 2~,-502,420.60 .............. 2'12,302.25 G-8 & RD 1874 2,502,425.63 212,299.39 G-6 1879 2,502,429.40 21 2,300.83 G-32 1882 2,502,426.27 212,303.38 G-16 1879 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 t386 1389 1389 1386 1382 1378 1376 ..... 1378 ...... 1382 1 385 1383 1381 1. Operations performed: ~--- STATE OF ALASKA AL/- ~, OIL AND GAS CONSERVATION COMMIS, .,N REPORT OF SUNDRY WELL OPERATIONS Operation shutdown __ Stimulate __ Plugging __ Pedorate __ Pull tubing .._. Alter casing __ Repair well __ Pull tubing __ Other X 2. Name of Operator ! 5. Type of Well: / Development ~ Ilninn t0ii f':nmr)anv of California ('UNOCJ~L) Exploratory~ 3. Address Stratigraphic_ P.O. Box 190247, Anch, Ak., 99519-024 Service__ 4. Location of well at surface Conductor #45, Leg #2 87, ' & 1 82' f SE Cor. Sec 29 TgN-R13W SM Att-~of~ro]~ct,vel~rvalup p uu ,,,u W O , At effective depth At total depth Cancel 6. Datum elevation (DF or KB) R T 99' MSLfeet 7. Unit or Property name TBU 8. Well number G-8rd 9. Permit number/a~._p~zq~a~ number 10. APl n u ~),~L20085_01 50-- 12. Present well condition summary Total depth: measured true vertical 11,750' feet Plugs(measured) 9,866 ' feet Effective depth: measured true vertical 11.485' feet Junk(measured) 9,633 feet Casing Length Structural Conductor 358 ' 590 ' Surface 3103 ' Intermediate 7820 ' Production 4351 ' Liner Perforation depth: Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 11. Field/Pl~mlockfm & "G" zon Size Cemented Measureddepth ~ueverticaldepth 26" Driven 358' 358' 16" 1250 sxs 590' 590' 13 3/8" 2300 sxs 3103' 2786' 9 5/8" 3300 SXS 7820 6457' 7" 1130 SXS 7396'-11,747' 6127'-9860' measured 11.332'-11.~.02' 11.294'-11.;;24'. 11.102'-11.132' 11,058'-11 078t, 10,668'-].0 708', 10,620'-10,645t truevertical 9,498'-9,560', 9,464'-9,491' , 9,294'-9,320' , 9,255'-9,272' 8,906'-8,943', 8,863'-8,885' 2 3/8", 4.6# $ 7299', 3 1/2", 9.2" N-80 ~ 10,873', 2 3/8", 4.6# ~ 10,951' Otis 3 1/2" sssv ~ 324'; Baker A-5 pkr. 10,492'-10,501' _ 14. Intervals treated (measured) We ll Treatment description including volumes used and final pressure work Representative Daily Average Production or Injection Data '"' ~,,~horage '" OiI.Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ ! Daily Report of Well Operations __ Oil __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed / / "Roy"D. Roberts Title Environmental Spec. Service D]~/03/88 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE STATE OF ALASKA -' ALASKA OIL AND GAS CONSERVATION COMMISSIL,. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate X Plugging ' Pedorate__ Pull tubing __ Alter casing __ Repair well __ Pull tubing __ Other 2. Name of Operator U~ION OIL COt,~'A_N~ OF CALIFOt~T__.A 3. Address P.O. BOX 1.90247 A_NCHORAGE, A/z,. 99519-0247 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface CONDUCTOR 45 LEG 2 1874' N & 1382' W OF SE CORNER SEC 29, At top of productive interval 3688' S & 3902' E F/SURFACE LOCATION At effective depth 4163' S & 4131' E F/SURFACE LOCATION ,~t total depth SAME AS ABOVE) T9N, R13W S.M. 12. Present well condition summary Total depth: measured true vertical .. ll, 747 feet Plugs(measured) ,. 9,854 feet Effective depth: measured 11,747 feet Junk (measured) true vertical 9,854 feet Casing Length Size Cemented Measured depth True vertical depth Structural 358 ' 20" DRIVEN 358 ' 358 ' Conductor 589 ' 16" 1200 SX 589 ' 589 ' Surface 3103' 13-3/8" 2300 SX 3103' 2774' Intermediate 7820' 9-5/8" SHOE- 1500 SX 7820' 6444' Production DV- 1800 SX I~iner 4351 ' 7" 830 SX 7396 ' -11,7.47 ' 6115 ' -9854' Perforation depth: measured (SEE ATTACHED) true vertical Tubing (size, grade, and measured depth) LS: SS: 3-1/2" N-80 0-144' 2-7/8" N-80 packers and SSSV (type and measured depth) 2- 3 / 8", N- 80 7334 ' - 10,564 ' BAY. ER "AL-S" DUAl, PKR. @ 10,488', BAKER "F-I" PKR @ 10,875' SSSV 13. Stimulation or cement squeeze summary (SEE ATTACHED) I ntervaJs treated (measured) 3-1/2", N-80 0-7299', 2-3/8", N-80 7299'-10,951' 144'-7334' @ 324' (LS) & 356' (SS', Treatment description including volumes used and final pressure 4000 GAT., 7-1 / 2% HCL PLUS ADDITIVES, 4500 PSI 14. Representative Daily,Average Production or Injection Oata OiI-Bbl Gas-Mcf Water-Bbl Casing P.ressure Tubing Pressure Prior to well operation 1 -- 9 990 PSI 120 PSI Subsequent to operation 40 -- 426 1100 PSI 230 PSI 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. t hereby certify that the foregoing is true and correct to the best of my knowledge. ned Roy::D. Roberts Title Env i ronmenta 1 E. nq i neer Form 10-404 Rev 06/15/88 Date 10/31/88 SUBMIT IN DUPLICATE 6. Datum elevation (DF or KB) 99' RT ABOVE MSL feet 7. Unit or Property name TRADING BAY UNIT STATE 8. Well number G-8 RD/SS 9. Permit number/approval number 8-313 '10. APl number 50-- 733-20085-01 11. Field/Pool MCARTHUR RIVER FIELD TBUS G-8RD PERFORATION INTERVAL MEASURED DEPTH 10,620'-10,645' 10,668'-10,708' 11,058'-11,078' 11,102'-11,132' 11,294'-11,~24' 11,~2'-11,~52' 11,~52'-11,402' TRUE VERTICAL DEPTH 8844'-8869' 8912'-8952' 9145'-9165' 9294'-9324' 9463'-9493' 9501'-9521' 9521'-9571' INTERVALS 25' 40' 20' 30' 30' 20' 50' 0093C UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO LEASE Tradinq Bay Unit State WELL NO, G-8 RD/S~iELD Mc Arthur River DATE E.T.D, DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8/8/88 8/9/88 8/10/88 8/11/88 8/12/88 8/18/88 11,490 Rig up HOWCO equipment. Test pump lines and Otis 1-1/4" coiled tubing unit to 5000 psi. Test lubricator, BORE, and lower pipe rams to 3000 psi. Ran in hole with 2-1/4" mill on a 1-3/4" mud motor and clean out to 7334'. CBU. Rulled out of hole. Rig down mud motor and mill. Make up 1.75" jet nozzle and ran in hole. Ran in hole with 1.75" down jet cleaning tool. Clean out heavy scale or bridges at 9423' and 9674'. Also heavy scale at 9743'-10,300'. Unable to clean out past GLM at 10,300'. Rull out of hole. Rig down jet tool. Make up a 1.8" flat bottom mill on a 1-3/4" mud motor and ran in hole. Clean out from 10,300'-10,565. CBU. Rull out of hole. Made up and ran in hole with Otis Hydro-Blast side jet cleaning index tool. Using (6) .052" jets, 2 sets of three 180° apart. Using FIW with .3% XC polymer, KCL and 0.5 lb/bbl Ammonia Rersulfate as a breaker at 120° F. Working on pass #3 of six and paying particular attention at each GLM. Continue with Otis Hydro Blast side jet cleaning index tool. Using (6) .052" jets, 2 sets of three 180° apart. Using FIW with .3% XC polymer, KCL and 0.5 lb/bbl Ammonia Rersulfate as a breaker at 120° F. Completed all six required passes with jet tool. Rig down Otis CTU and rig up Myers wireline. Test lubricator to 3000 psi. Ran in hole with 2.3" swedge to crossover at 7334', tubing clear. Rulled out of hole. Make up 1.78" swedge and ran in hole to the tubing tail at 10,563', tubing clear. Rulled out of hole. Down Myers wireline and rigged up Otis l-l/4" coiled tubing. Make up TAM l-il/16" inflatable packer and ran in hole to 10,540'. Shut down gas lift and displaced tubing with 3% KCL FIW. Drop setting ball and displaced with 13 bbls. Set packer at 10,540' with 1800 psi. Rressure back side to 600 psi. Acidize "G" zones 3 & 4 using HOWCO as follows: 2000 gal 7-1/2% HCL with .2% low surfactant 300, 6% CLA-STA XP, 15#/lO00 gal L-58, .4% A-250 at 0.6 BRM 3800 psi. 1000 gal 3% KCL FIW with .6% CLA-STA XP at .6 BPM 4100 psi. 1000 gal 3% KCL FIW at .7 BPM 4200 psi. 400 gal gelled 3% KCL FIW with .5#/gal Benzoic acid granules. 2000 gal 7-1/2% HCL plus additives as above at 1BPM 4000 psi to 0.7 BRM 4500 psi with diverter to perfs. 1000 gal 3% KCL FIW with CLA-STA XP at .75 BPM 4500 psi. Displaced with 42 bbls 3% KCL FIW at .68 BPM 4500 psi. Released packer and pulled out of hole. Released well to production at 0430 hours 8/13/88. Rigged up Myers wireline unit over G-8RD SS. Ran Amerada pressure and temperature recorders to tubing tail at 10,564'. Ran one hour FBHP survey of 1634 psi, 182° F. Rulled out of hole with recorders. Shut down gas lift and flushed G-zone perfs with 8000 gal of diesel with additives. Diesel in place at 2230 hours 8/18/88. Released rig to G-31L at 2400 hours 8/18/88. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI!--'ON APPLICA, ION FOR SUNDRY APF,- OVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Co. of California 99' RT above MSL feet 3. Address P.O. Box 190247, Anchorage, At( 99519-0247 4. Locatio~ of well at surface Conductor ¢/45 Leg ¢/2 1874'N & 1382' W of SE corner Sec 29, T9N, R13W SM At top of productive interval @10,620' MD 3688.12' S & 3901.75' E of ~He Surface Loc At effective depth @ 11750' ~','D 4163.13'S & 4130.87 E of the Surface Loc. At total depth (Same as Above) 6. Unit or Property name Trading Bay Unit 7. Well number TBUS 6-8 RD Sh-or't String 8. Permit number . 78-45 9. APl number 50--733-20085-01 10..PoO~_zone 3&4 11. Present well condition summary Total depth: measured 11,747' feet Plugs (measured) true vertical 9,863' feet Effective depth: measured 11,747 ' feet ,Junk (measured) true vertical 9,863 ' feet Casing Length Size Cemented Structural 358 ' 20 ' Drive Conductor 589 ' 16" 1200 sx Surface 3103', 13-3/8" 2300 sx Intermediate 7802' 9-5/8" Shoe-1500 sx Production DV-1800 sx Liner 4351 ' 7" 830 sx Perforation depth: measured ( See Attached) true vertical Measured depth 358' 589' 3103' 7802' 11747' True Vertical depth 358' 589' 2783' 6440' 9861' Tubing (size, grade and measured depth) LS: 3-1/2" N-80 0-7299' SS: 2-7/8" N-80 0-7334' 2-3/8" N-80 7299'-10,950'' 2-3/8" N-80 7334'-10, · Packers and SSSV (type and measured depth)~aker ~g~g~ Dual Pkr. @@ ~?~' ~¥-~g' t. ~aKer Sin$Ie PEr. 1 ' ' 12.Attachments Description summary of proposal t~ Detailed operations program [] BOP sketch L_3 13. Estimated date for commencing operation May 1, 1988 14. If proposal was verOally approved Name of approver Date approved 15. I aereoy certify that the foregoing is true and correct to the best of my knowledge S i g n e d .~/~,¢,~...2 '~. ),~.~z...,~ Title Environmental Engineer ~oy Roberts 'J'";""~ Commission Use Only Conditions of approval Notify commission so representative may w~tness [] Plug integrity [] BOP Test F3 Location clearance Approved Copy Returned ORIGINAL SIGNED BY ~ ~, ',~, LONNIE C. SMITH Approved by Commissioner Date 4/25/88 by order of -- the commission 64' Form 10.403 Rev 12-1-85 Submit in triplicate April 14, 1988 TBUS G-8RD PERFORATION INTERVAL MEASURED DEPTH TRUE VERTICAL DEPTH INTERVALS 10,620' - 10,645' 10,668' - 10,708' 11,058' - 11,078' 11,102' - 11,132' 11,294' - 11,324' 11,332' - 11,352' 11,352' - 11,402' 8844' - 8869' 8912' - 8952' 9145' - 9165' 9294' - 9324' 9463' - 9493' 9501' - 9521' 9521' - 9571' 25' 40' 20' 30' 30' 20' 50' TBUS G8-RD SUMMARY OF PROPOSAL 1) 2) 3) 4) 5) 6) MIRU coil tubing unit. Clean out the short to 10,562'. Return well to production and change the GLV's necessary to allow the well to lift from bottom. Pump acid through coil tubing using a packer as follows: A) 2000 gal 7-1/2% HCL w/ clay stabilizer. B) 2000 gal FIW w/ 2% KCL and clay stabilizer. C) 400 gal gelled acid w/ 1/2# per gal wide range unibeads. D) 2000 gal 7-1/2% HCL w/ clay stabilizer. E) 2000 gal FIWw/ 2% KCL and clay stabilizer. Return the well to production for one week. Pump diesel flush through coil tubing using a packer as follows: A) 8000 gal diesel w/ 2% anionic surfactant B) 270 gal filtered diesel Shut well in for 24 hours then return to production. 0531N STATE OF ALASKA - ALAS OIL AND GAS CONSERVATION COM. SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing E] ~ Plugging ~ Stimulate [] Pull tubing ~ Amend order [] Perforate ~i( Other Time extension Change approved program /, 2. Name of Operator Un.ion 0.i..1. Company of' Calif'ornia (UN00/~L) 3. Add~.Sc~' Box 190247, Anch, Ak., 99519-0247 4. Loc,~)(~d~lfc~/~L a~z~r, faic_.~g i/f2 1874' N & 1382' W o¢ SE Cot., Sec 29 TgN-R13W SM At top of productive interval At effective depth At total depth 11. Present well condition summary 5. Datum elevation (DF or KB) RT 99' IvJSLfeet 6. Unit or Property r~g..je 7. Well number G-8rd 8. Permit number 78-45 9. APl num~3-20085-O1 50-- 10. Pool Hemlock fm & "G,' zor RECEIVED Total depth: measured 11,750' feet true vertical 9,866' feet Effective depth: measured '11,485 ' feet true vertical 9,633 feet Casing Length Size Structural Conductor 358' 26" 590 ' 16" Surface 3103' 13 3/8" Intermediate 7820' 9 5/8" Production 4351 ' 7" Liner Perforation depth: measured true vertical Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth Driven 358' 358' 1250 sxs 590' 590' 2300 sxs 3103' 2786' 3300 sxs 7820 6457' 1130 sxs 7396'-11,747' 6127'-9860' 11,332'-11,402', 11.294'-.11,324' 11,102'-11.132' 11,058'-11,078', 10,668'-10,7081, 10,620'-10,645~ 9,498'-9,560', 9,464'-9,491', 9,294'-9,320', 9,255'-9,272' 8,906'-8,943', 8,863'-8,885' Tubing (size, grade and measured depth) 2 3/8", 4.6~'~ 8 7299' , 3 1/2", 9.2" N-80 ~ 10,873', 2 3/8", 4.6¢~ ® 10,951' Packers and $$$V (type and measured depth) Otis 3 1/2" SSSV ~ 324'; Baker ~-5 pkr. 10,492' -10 ~ 501 ' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 4-22-88 14. If proposal was verbally approved Name of approver /O- ¢0~/ // ~ ~f~¥ Date approved 15. I hereby certify that .the foregoing is true.,and correct to the best of my knowledge Signed ,,!,~'~'~_~/~-;,._ ,o..,¢)~y~,~o~b~C/~s Title Environmental Spec. Commission Use Only Date 04/21/88 Conditions of approval Approved by Form 10-403 Rev 12-1-85 I Notify commission so representative may witness Approval [] Plug integrity [] BOP Test [] Location clearanceI '~sioner le by order of the commission Date Submit in triplicate le e e G-8RD L PERFORATION PROCEDURE Rig up E-Line Unit. Pressure test lubricator to 2500 psi. RIH with 2 1/8" perforating guns, 4 SPF, 0° phasing. Reperforate underbalanced or flowing as follows: HB-i 10,058'-10,078' DIL (20') HB-4 11,294'-11,324' DIL (30') HB-4 11,332'-11,402' DIL (70') Rlg down E-Line Unit. Place well on production, flowing to test separator. Upon direction from reservoir, rig up E-Line unit and prepare to open up 37' new Bench 2 interval. RIH with 2 1/8" perforating guns, 4 SPF, 0© phasing. Perforate underbalanced or flowing as follows: HB-2 11,138'-11,175' DIL (37') Rig down E-Line unit. Place well on production. Form D-lOO1-A . UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET A Page No. I LEASE Trading Bay Unit. WELL NO. G-8 WO CONTRACTOR Conservative Drilling Company FIELD McArthur Ply'er Field TYPE UNIT National 1320 UE BEGAN 5/12/83 COMPLETED 6/25/83 ELEVATIONS: GROUND PERMIT N0./~8-45 SERIAL NO. ADL 18730 - CASING HEAD COMPANY E~GI~EER Gra,~am,_McA~lister~ Abernathy~ Bush TUBING HEAD APPROVE _D_'~~'~ ~_~~~ - ROTARY DRIVE BUSHING 99' MLLW CASING & TUBING RECORD SIZE DEPTH WEIGHT GRADE REMARKS 20" 358' 1/2" Wall Drive 16" 589' 75# 0-55 13 3/8" 3103' 61# 0-55 9 5/8" 7820' 43.5# N-80 7" 11747' to 29# N-80 7396' Pipe Cmtd w/ 1200 sxs cmt Cmtd w/ 2300 sxs cmt Cmtd thru shoe w/ 1500 sxs & thru DU w/ 1800 sx Cmtd w/ 830 sxs PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 8/3/78 11264' to 11266' 11623' 8/8/78 10668' to 10708' 11230' 8/9/78 10620' to 10645' 11230' 8/12/78 11294' to 11324' 11623~ 8/12/78 11332' to 11402' 11623' 8/13/78 10668' to 10708' 11623' 1/30/79 11430' to 11432' 11623' 2/2/79 11264' to 11266' 11285' ~2/8/79 11332' to 11402' 11263' BS #1 Production Production Production Production Production BS BS Production Squeezed w/ 100 sxs cmt G-4 - Open G-3 - Open Hemlock Bench #4 - Open Hemlock Bench #4 - Open Reperf G-4 - Open Squeezed w/ 150 sxs Squeezed w/ 250 sxs Reperf H.B. #4 - Open INITIAL PRODUCTION AFTER REPAIR DATE INTERVAL NET OIL CUT GRAV. C.R. T.P. CHOKE MCF GOR REMARKS WELL HISTORY PRIOR TO REPAIR COMPLETION DATE: 12/20/79 LAST COMPLETION NO. 2 PRODUCING INTERVAL: INITIAL PRODUCTION: LAST REGULAR PROD. & DATE: CUMULATIVE PRODUCTION: REASON FOR REPAIR: To reperf "G" zone and acidize same. Also~ to recover wireline fish left in hole. F(~m D-i O01-B LEASE Trading Bay Unit COMPLE~I'ON D'ATE 6/25/83 UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B 2 PAGE NO. WELL NO. G-8 WO FIELD McArthur River Field AP'PROVED DATE INTERVAL' ETD REASON PRESENT CONDITION 2/09/79 11324 2/09/79 11668 2/09/79 10620 6/15/83 11352 6/16-/83 11332 6/16/83 11294 6/16/83 11102 6/16/83 11058 6/16/83 10668 6/16/83 to 11294 to 10708 to 10645 to 11402 to 11352 to 11324 to 11132 to 11078 to 10708 10620 to 10645 11623 11623 11623 11490 11490 11490 11490 11490 11490 11490 Producti on Producti on Production Producti on Production Production Production Producti on Producti on Producti on Hemlock Bench #4 - Open G-4 - Open G-3 - Open H.B. #4 Reperf - Open H.B. #4 Reperf - Open H.B. #4 Reperf - Open H.B. #2 - Open H.B. #1 - Open G-4 Reperf - Open G-3 Reperf - Open WELL HEAD ASSEMBLY TYPE: Cameron Iron Works CASING HEAD: Schaffer KD 12" 3000 psi w/ 2" Cameron Valves SON 13 3/8" CASING HANGER: Schaffer KD 12" - 9 5/8" Model KD - KS Slips CASING SPOOL: TUBING HEAD- Cameron DC-B 12" 3000 psi x 10" 5000 psi TUBING HANGER: Dual Cameron 3 1/2" TUBING HEAD TOP: 3 1/2" EUE MASTER VALVES: CHRIST~S TREE TOP CONN.: 3 1/2" EUE NOTE: The DC-B spool need work - the tie-downs were very difficult to operate. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT WELL NO. G-8 WO FIELD MC ARTHUR RIVER FIELD TUBING DETAIL-LONG STRING JTS ,, 2 11 6 6 12 12 DESCRIPTION LENGTH 2 3/8" Mule Shoe 2 3/8" 4.6# N-80 Butt 2 3/8" Otis "XN" Nipple 2 3/8" 4.6# N-80 Butt 2 3/8" x 3 1/2" X.O. Baker Seal Assembly .69' 27.83' .55' 30.00' .86' 15.89' 9 5/8" Baker "F-i" Packer $ 10,856' OIL, 10,877' DPM Baker Locator 3 1/2" x 2 3/8" X.O. 2 3/8" Pup 2 3/8" 4.6# N-80 Butt 2 3/8" Otis "XA" Sleeve 2 3/8" 4.6# N-80 Butt 2 3/8" x 2 7/8" X.O. 2 7/8" Blast Joints (3.688" O.D.) 2 7/8" x 2 3/8" X.O. 2 3/8" 4.6# N-80 Butt 2 3/8" Otis "XA" Sleeve 2 3/8" 4.6# N-80 Butt 2 3/8" Butt x 8rd X.O. Baker AL-5 Dual Packer 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Otis "XA" Sleeve 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" N-80 Butt Tbg 2 3/8" Pup · 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups (2) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups (2) .84' .89' 5.12' 31.44' 2.58' 89.37' .74' 118.00' .76' 60.07' 2.50' 62.47' 1.20' 10.58' 30.67' 2.55' 118.61' 6.10' 178.55' 6.10' 58.15' 7.06' 61.75' 6.08' 328.23' 6.11' 179.20' 5.02' 148.02' 6.50' 57.25' 5.08' 58.84' 4.07' 30.05' 5.13' 178.12' 5.78' 364.13' 5.79' 211.67' 8.18' 267.49' 5.80' 209.49' 4.08' 361.36' 6.12' 242.88' 8.59' BTM 10,950.82' 10,950.13' 10,922.30' 10,921.75' 10,891.75' 10,890.89' 10,875.00' 10,874.16' 10,873.27' 10,868.15 10,836.71' 10,834.13' 10,744.76' 10,744.02' 10,626.02' 10,625.26' 10,565.19' 10,562.69' 10,500.20' 10,499.02' 10,488.44' 10,457.77' 10,455.22' 10,336.61' 10,330.51' 10,151.96' 10,145.86' 10,087.71' 10,080.65' 10,018.90' 10,012.82' 9,684.59' 9,678.48' 9,499.28' 9,494.26' 9,346.24' 9,339.74' 9,282.49' 9,277.41' 9,218.57' 9,214.50' 9,184.45' 9,179.32' 9,001.20' 8,995.42' 8,631.29' 8,625.50' 8,413.83' 8,405.65' 8,138.16' 8,132.36' 7,922.87' 7,918.79' 7~557.13' 7,551.31' 7,308.43' TOP 10,950.13' 10,922.30' 10,921.75' 10,891.75' 10,890.89' 10,875.00' 10,874.16' 10,873.27' 10,868.15' 10,836.71' 10,834.13' 10,744.76' 10,744.02' 10,626.02' 10,625.26' 10,565.19' 10,562.69' 10,500.22' 10,499.02' 10,488.44' 10,457.77' 10,455.22' 10,336.61' 10,330.51' 10,151.96' 10,145.86' 10,087.71' 10,080.65' 10,018.90' 10,012.82' 9,684.59' 9,678.48' 9,499.28' 9,494.26' 9,346.24' 9,339.74' 9,282.49' 9,277.41' 9,218.57' 9,214.50' 9,184.45' 9,179.32' 9,001.20' 8,995.42' 8,631.29' 8,625.50' 8,413.83' 8,405.65' 8,138.16' 8,132.36' 7,922.87' 7,918.79' 7,557.43' 7,551.31' 7,308.43' 7,299.84' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT WELL NO. G-8 WO FIELD MC ARTHUR RIVER FIELD TUBING DETAIL-LONG STRING JTS 19 23 4 10 12 4 3 10 18 6 12 2O 2O DESCRIPTION 2 3/8" X 3 1/2" X.O. 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurry-Hughes MHO GLM (4 1/8" FN) 3 i/2" 9.2# N-80 Butt Tbg 3 i/2" Pup 3 i/2" 9.2# N-80 Butt Tbg 3 i/2" Pup 3 i/2" 9.2# N-80 Butt Tbg 3 i/2" McMurry-Hughes MHO GLM (4 1/8" FN) 3 i/2" 9.2# N-80 Butt Tbg 3 i/2" Pup 3 i/2" 9.2# N-80 Butt Tbg 3 I/2" Pup 3 i/2" 9.2# N-80 Butt Tbg 3 i/2" Pup 3 i/2" 9.2# N-80 Butt Tbg 3 I/2" Pup 3 i/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurry-Hughes MHO GLM (4 1/8" FN) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurry-Hughes MHO GLM (4 1/8" FN) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg ~ 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Otis Ball Valve 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pups (4) CIW Dual Tubing Hanger Landed Below R.T. LENGTH .43' 571.09' 6.22' 701.16' 6.10' 119.05' 4.80' 300.81' 6.30' 358.25' 5.10' 117.91' 5.14' 208.65' 4.07' 208.61' 5.10' 242.57' 5.15' 119.25' 4.90' 92.95' 6.25' 297.47' 5.11' 542.63' 5.10' 236.79' 5.03' 270.20' 5.12' 239.09' 6.20' 60.40' 5.08' 178.39' 5.02' 359.44' 5.00' 61.99' 8.62' 596.69' 4.83' 604.81' 4.85' 147.67' 4.81' 213.23' 2.23' 272.85' 13.50' 1.00' 36.83' BTM 7,299.84' 7,299.41' 6,728.32' 6,722.10' 6,020.94' 6,014.84' 5,895.79' 5,890.99' 5,590.18' 5,583.88' 5,225.63' 5,220.53' 5,102.62' 5,097.48' 4,888.83' 4,884.76' 4,676.15' 4,671.05' 4,428.48' 4,423.33' 4,304.08' 4,299.18' 4,206.23' 4,199.98' 3,902.51' 3,897.40' 3,354.77' 3,349.67' 3,112.88' 3,107.85' 2,837.65' 2,832.53' 2,593.44' 2,587.24' 2,526.84' 2,521.76' 2,343.37' 2,338.35' 1,978.91' 1,973.91' 1,911.92' 1,903.30' 1,306.61' 1,301.78' 696.97' 692.12' 544.45' 539.64' 326.41' 324.18' 51.33' 37.83' 36.83' TOP , 7,299.41' 6,728.32' 6,722.10' 6,020.94' 6,014.84' 5,895.79' 5,890.99' 5,590.18' 5,583.88' 5,225.63' 5,220.53' 5,102.62' 5,097.48' 4,888.83' 4,884.76' 4,676.15' 4,671.05" 4,428.48' 4,423.33' 4,304.08' 4,299.18' 4,206.23' 4,199.98' 3,902.51' 3,897.40' 3,354.77' 3,349.67' 3,112.88' 3,107.85' 2,837.65' 2,832.53' 2,593.44' 2,587.24' 2,526.84' 2,521.76' 2,343.37' 2,338.35' 1,978.91' 1,973.91' 1,911.92' 1,903.30' 1,306.61' 1,301.78' 696.97' 692.12' 544.45' 539.64' 326.41' 324.18' 51.33' 37.83' 36.83' LEASE TRADING BAY UNIT SHEET D 5 RAGE NO. UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-8 WO FIELD MC ARTHUR RIVER FIELD TUBING DETAIL-SHORT STRING OTS 2 10 4 9 14 42 52 55 71 DESCRIPTION 2 3/8" Coupling 2 3/8" Otis "XN" 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Butt to 8rd X.O. Baker AL-5 Dual Packer 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Otis "XA" Sleeve 3/8" 4.6# N-80 Butt Tbg ~ 3/8" Otis RW-4 GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt.Tbg 2 3/8" Otis RW-4 GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbq 2 3/8" Otis RW-4 GLM (2 ~/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg ~,, 2 3/8" Camco XBMG GLM (2 7/0 FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" McMurry-Hughes MHO GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups (2) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups ~ 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups (2) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" x 2 7/8" X.O. 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Camco XBMG GLM (3 1/2" FN) 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Camco XBMG GLM (3 1/2" FN) 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" MACCO GLM (3 1/2" FN) 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Pup 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" MACCO GLM (3 1/2" FN) 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Otis Ball Valve 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" x 3 1/2" X.O. 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pups (4) CIW Dual Tubing Hanger Landed below R.T. LENGTH .72' .58' 60.77' .87' 9.48' 6.08' 57.83' 2.55' 119.04' 5.68' 215.90' 5.78' 57.96' 6.08' 117.73 ' 5.12' 176.71' 5.10' 59.10' 5.80' 304.20' 5.00' 122.58' 6.12' 242.52' 4.07' 118.64' 5.05' 209.48 ' 5.04' 29.12' 4.06' 182.10' 7.64' 267.81' 7.18' 419.64' 3.94' 149.11' 7.18' 209.84' .43' 31.37' 5.84' 1,283.91' 5.87' 1,587.15' 6.16' 214.41' 5.11' 1,670.03' 6.13' 2,159.61' 1.98' 212.89' .39' 89.96' 13.75' 1.00' 38.94' BTM 10,564.13' 10,563.41' 10,562.83' 10,502.06' 10,501.19' 10,491.71' 10,485.63' 10,427.80' 10,425.25' 10,306.21' 10,300.53' 10,084.63' 10,078.85' 10,020.89' 10,014.81' 9,897.08' 9,891.96' 9,715.25' 9,710.15' 9,651.05' 9,645.25' 9,341.05' 9,336.05' 9,213.47' 9,207.35' 8,964.83' 8,960.76' 8,842.12' 8,837.07' 8,627.59' 8,622.55' 8,593.43' 8,589.37' 8,407.27' 8,399.63' 8,131.82' 8,124.64' 7,705.00' Y,YOi.06' 7,551.95' 7,544.77' 7,334.93' 7,334.50' 7,303.13' 7,297.29' 6,013.38' 6,007.51' 4,420.36' 4,414.20' 4,199.79' 4,194.68' 2,524.65' 2,518.52' 358.91' 356.93' 144.04' 143.65' 53.69' 39.94' 38.94' TOP 10,563.41' 10,562.83' 10,502.06' 10,501.19' 10,491.71' 10,485.63' 10,427.80' 10,425.25' 10,306.21' 10,300.53' 10,084.63' 10,078.85' 10,020.89' 10,014.81' 9,897.08' 9,891.96' 9,715.25' 9,710.15' 9,651.05' 9,645.25' 9,341.05' 9,336.05' 9,213.47' 9,207.35' 8,964.83' 8,960.76' 8,842.12' 8,837.07? 8,627.59' 8,622.55' 8,593.43~ 8,589.37' 8,407.27~ 8,399.63' 8,131.82~ 8,124.64~ 7,705.00' 7,701.06~ 7,551.951 7,544.77' 7,334.937 7,334.50~ 7,303.13' 7,297.29~ 6,013.38: 6,007.51~ 4,420.36 4,414.20 4,199.79 4,194.68 2,524.65 2,518.52 358.91 356.93 144.04 143.65 53.69 39.94 38.94 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 5/12/83 DAILY COST: ACC COST: AFE AMT: 2 5/13/83 DAILY COST: ACC COST: AFE AMT: 5/14/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 11600' ETD (Junk) 26" C. 350' 16" C. 590' 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' FIW $ 38,060 $ 38,060 $ 940,000 11750' TD 11600' ETD (Junk) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' FIW $ 33,634 $ 71,694 $ 940,000 11705' TD 11600' ETD (JUNK) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 37,654 $ 109,348 $ 940,000 Commenced operations ~ 00:01 hrs 5/12/83. Bled press off LS & SS & 9 5/8" csg. Well is dead but has not been filled w/ fluid. RU Myers WL on SS. Pulled ball valve. RIH w/ impression block & tagged WL. Fish & drop bar top e 572'. Moved Myers to LS. RIH & pulled ball valve on Myers. RU Go 7/16" WL w/ 2 5/16" OS dressed w/ i 1/2" grapple spang jars, oil jars & 15' of i 1/2" sinker bar. RIH in SS. Engauged fish & jarred top drop bar out (8 hrs). Markings indicate it had been driven past the top of the second bar. Attempted to fish 2nd drop bar in SS 8 580' - could not stay latched onto fish. Opened "XA" sleeve in LS ~ 10483'. Attempted to open "XA" in LS @ 10817' but stuck shifting tool 8 10755'. Worked tools free & RD WL. Pumped dwn LS & up annulus w/ kcl fluid - recovered +300 bbls of oil. SS began to flow-due to under- balance. Took returns out SS while pumping dwn LS to fill SS w/ kcl fluid. Installled BPV's, removed tree, installed & tested BOPE. Mixed & pumped 10 F3 of Cai-Seal slurry dwn SS to lock-up WL. Cal-Seal slurry began setting up in lines. Pumped dwn LS & up SS to clear tbg. RU Go WL over LS & RIH w/ i 11/16" tbg cutte~r. Cut LS ® 10548' tbg meas (10565' WLM). RD Go WL, Mixed & pumped l0 F3 of Cal-Seal slurry dwn SS & displ w/ 2 7/8" tbg plug to top of fish ~ 580', Attempted to release A-5 pkr by pulling on LS - pkr would not release, RU Go WL on SS & RIH w/ 2 1/4" tbg cutter, Tagged tbg plug ® 576' WLM, Pulled up & made cut in SS 8 540' WLM (537' tbg meas). POOH w/ SS, UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 FIELD McArtht~ River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5/15/83 DAILY COST: ACC COST: AFE AMT: 5 5/16/83 DAILY COST: ACC COST: AFE AMT: 6 5/17/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 7671' ETD (Top of LS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 27,451 $ 136,799 $ 940,000 11750' TD 7671' ETD (Top of LS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 27,330 $ 164,129 $ 940,000 11750' TD 7671' ETD (Top of LS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 27,635 $ 191,764 $ 940,000 Pulled & LD SS f/ 537'. RU Go WL on LS & RIH w/ 1 13/16" tbg cutter. Cutter stuck ~ 7647' WLM (top GLM in 2 3/8" tbg). Could not free cutter. Mad cut & pulled WL out of rope socket leaving cutter in hole. Circ clean & POOH laying dwn LS f/ cut ~ 7671' tbg meas. RIH w/ 0S & tagged SS fish ~ 537' - could not latch onto fish. POOH - found hollow mill improperly dressed. Redressed mill & RIH - could not latch onto fish. POOH & chgd hollow mill insert. RIH - could not: latch onto fish. POOH. RIH w/ new grapple in 0S & latched onto fish ~ 537'. Made blind back-off. POOH & LD tbg & broken sections of WL. Pulled & LD 2 7/8" tbg f/ SS. Rec 6535' of 2 7/8" tbg, 1 sinker bar, 1 Kinley cutter, & +350' of WL. In- stalled 5" rams. RIH w/ WL spear on 5" DP. Rotated & picked up every 7 stds below 3000' Spear stopped ~ 5526'. Rotated ~ picked up 20M# overweight 'to pull loose. POOH. Reeled off 5300' of WL & cut + 3000' of wire off spear (total recovered of +9400'). Installed 2 3/8" rams & repaired seals in hinge on single gate. Repaired adjustment knob on drum brake. RIH w/ WL spear & 8 1/2" stop on 5" DR. Rotated & picked up 6000', 6500' & 7050' Ran in to 7072' (top of SS). Ricked up 2' & rotated. POOH. POOH w/ WL spear-had no recovery. RIH w/ OS cut-lip guide & screw-in sub to 7072'. Got over tbg but un- able to screw into top. POOH-screw- in sub was flared out. RIH w/ 8 1/2" impression block on DR to 7072'. Spudded down on top of SS to make impression. POOH - left entire lead portion in hole (IB was incorrectly made). RIH w/ 8 1/2"x7 1/2" rotary shoe & extension & RIH. Tagged fish ~ 7067'. Rotated & pushed f/ 7067' to 7079'. POOH & rec small pce of lead. RIH w/ 8 1/2" guide, hollow mill control, OS w/ 2 7/8" grapple, & top extension to 7072'. Dressed tbg top & turned 33 1/2 turns to the right to make up any loose jts. Pulled 190M# & grapple held. Picked up to remove kelly & grapple cam eloose w/ 20OM# upstrain (150M# is normal pickup). POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7 5/18/83 11750' TD POOH w/ fishing tools & rec a 2"x3" 7671' ETD (Top of LS) pce of lead & a short section of 7680' ETD (Top of SS) 2 7/8" SC coupling. Chgd grapple & 13 3/8" C. 3130' added i more top extension. RIH & 9 5/8" C. 7820' latched onto SS ~ 7072'. Pulled up 7" L. 7396-11747' to 3OM# over normal PU. RU Go WL & KCL-FIW RIH w/ i 11/16" tbg cutter on WL- DAILY COST: $ 31,907 ACC COST: $ 223,671 AFE AMT: $ 940,000 would not go below 7068' WLM. POOH w/ WL. Pulled up to 230M# (8OM# over normal pickup) on tbg & pulled loose. POOH & rec + 1/2 of a SC 2 7/8" coupling w~ich was packed full of lead. Changed out grapples & RIH. Latched onto SS ~ 7072' & RU Go WL. RIH w/ 1 11/16" tbg cutter-could not get past 7065' WLM. POOH w/ WL. Pulled up to 30OM# on tbg & parted same. POOH & rec 280.96' of 2 7/8" tbg & 327.26' of 2 3/8" tbg (608.22' total). Top of tubing was open and clear w/ no junk or bent tops. Top of SS now ~ +7680'. RIH w/ OS & 2 3/8" grapple to fish for LS ~ &671'. Tagged junk ~ 7401'. Rotated & pushed junk to 7676'. 8 5/19/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 7671' ETD (Top of LS) 7580' ETD (TOp of SS) 13 3/8" C. 3130' 9 5/8" C. ?820' 7" L. 7396-11747' KCL-FIW $ 29,321 $ 252,992 $ 940,000 Milled on junk ~ 7676'. POOH - rec small amt of lead f/ OS. RIH w/ 6"x3 1/2" rotary shoe to 7676' DPM. Rotated & milled f/ 7676' to 7685' DPM. POOH-marks showed possibly 2 fish in hole. RIH w/ cut-lip guide, 2 3/8" hollow mill control, & OS w/ 2 3/8" grapple-could not get over fish ~ 7676'. POOH. Changed rams to dual 2 3/8" & changed seals in single gate. RIH w/ 4 5/8" short catch OS for run #16. Rotated over fish. Latched onto fish & pulled loose w/ 2OM#. Pooh-markings indicated 2 fish. RIH w/ 4 1/2" x 2 3/8" rotary shoe & OS w/ 2 3/8" grapple. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 5/20/83 DAILY COST: ACC COST: AFE AMT: 10 5/21/83 11750' TD 7684' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 30,091 $ 283,083 $ 940,000 11750' TD 7684' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: $ 31,569 ACC COST: $ 314,652 AFE AMT: $ 940,000 RIH w/ BHA #17 (4 1/2" x 2 3/8" ro- tary shoe w/ OS & 2 3/8" grapple). Rotated & milled over TOF ~ 7676'. Latched onto fish & pulled loose w/ 2OM# pull over string wt. ROOH-rec 4.85' of LS & +12' of slivered SS which was corkscrewed around LS. RIH w/ BHA #18 (4" OD RH die collar) to TOF ~ 7681'. Rotated over fish 12 turns when came loose. ROOH-rec 3 small (8" max length) pieces of tbg. RIH w/ BHA #19 (4 1/16" RH die collar) & engauged fish ~ 7684'. Screwed onto fish but pulled off w/ lOM# over pull. Re-engauged fish & attempted blind backoff-just unscrewed die collar. Re-engauged fish a 3rd time & jarred up to 9OM# over string weight-pulled free. POOH-no recovery. RIH w/ BHA #20 (4 3/4" LH die collar). Rotated onto fish e 7684' & made blind backoff. POOH - rec 55.50' of 2 3/8" tbg w/ pin dwn. Top of this fish is a coupling ~ 7740'. RIH w/ BHA #21 (5 7/8" external tbg cutter on 5 3/4" washpipe). Worked over TOF ~ 7684' & located coupling ~ 7706'. Attempted outseide out ~ 7709'-no good. POOH-flipper dogs worn out Replaced burned out motor on draw- works. RIH w/ BHA #22 (4" external tbg cutter on 4" washpipe). Located coupling ~ 7706' & attempted outside cut ~ 7708'. POOH - had no recovery. Found 2 flipper dogs gone & 3 worn thru while 1 cutter was broken. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11 5/22/83 DAILY COST: ACC COST: AFE AMT: 12 5/23/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 7708' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 40,796 $ 355,448 $ 940,000 11750' TD 7740' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 33,793 $ 389,241 $ 940,000 Tested BOPE. RIH w/ BHA #23 (5 3/4" cut-lip guide, 2 3/8" hollow mill control extension, OS w/ 2 3/8" grapple, & 5.5' of top extension). Latch onto fish ~ 7684'. RIH w/ 1 7/16" sinker bar on WL - could not get below TOF ~ 7684'. POOH w/ WL. Pulled 7OM# over string wt & pulled loose. POOH - rec 24' of 2 3/8" tbg f/ cut ~ 7708'. RIH w/ BHA #24(same as #23 w/o top extension) to 7708'. Latched onto fish & RIH w/ 1 13/16" broach on 1 1/2" sinker bar & spang jars on Myers WL. Worked into TOF ~ 7708' & RIH to 7834'-could not work any deeper. Pulled back up to TOF ~ 7708' & worked thru several times - ok. POOH & RD Myers. RU Go WL & RIH w/ 1 13/16" jet cutter to 7836'. POOH w/ WL. Pulled up to 240M# on tbg - did not pull loose. RIH w/ jet cutter. Pulled 82M# over string wt & cut tbg ~ 7810' WLM. POOH w/ WL - WL tools hung up in fishing tools ~ 7708'. Strip out of hole w/ WL & 1 13/16" tbg cutter. Rec 102.27' of 2 3/8" tbg f/ cut ~ 7810' & WL tools. RIH w/ BHA #25 (cut-lip guide, btm ex- tension, 0S w/ 2 3/4" grapple, top sub) to TOF ~ 7740'. Latched onto fish & pulled off fish w/ 25M# over- pull. Could not re-engauge fish. POOH - rec a 2.7" OD SC coupling. RIH w/ BHA #26 (cut-lip guide, btm extension, 0S w/ 2 3/8" grapple, top sub). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 13 5/24/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 7740' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 28,579 $ 417,820 $ 940,000 RIH w/ BHA #26 (OS w/ 2 3/8"'grap- ple) & latched onto fish ~ 7740'. RU Myers & RIH w/ i 13/16" broach to tag ~ 7809'. POOH. RD Myers & RU Go WL. RIH w/ i ll/16" chemical cutter - stopped ® 7799' WLM. POOH. RD Go WL & RU Myers. Reran i 13/16" broach - stopped ~ 7809' & was stuck. Oarred loose & POOH (possible crimp in tbg ~ 7809'). Circ dwn DR to clean any possible junk. RIH w/ i 1/2" sinker bars (22' long) - stopped ~ 7818'. POOH - had some drag off btm. Reran 1 13/16" broach while pulling on fish w/ 6OM# overpull - broach stopped ~ 7809'. POOH. RD Meyers. Ru Go WL & ran l" tools (+22' long) - stopped ® 7848'. Logged GLM ~ 7804' w/ CCL. POOH. RIH w/ 1 3/8" ARRS jet cutter on Go WL to 7840'. Pulled up to 7827' & shot cutter w/ 210,000# pull on drill pipe (45M# overpull). Pipe parted in 5 mins. POOH w/ WL. Strapped out of hole w/ DR. 14 5/25/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 7833' ETD (Top of SS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 30,550 $ 448,370 $ 940,000 POOH - rec 92.76' including GLM) of 2 3/8" fish (determined to be SS). Top of SS at 7833'. RIH w/ BHA #27 (cut-lip guide, bottom extension, OS bowl w/ 2 3/8" grapple, top sub). Dressed top of LS at 7810' and latched onto fish. Pulled up to 206M#. RU Myers WL through gooseneck. RIH w/ i 13/16" broach. Passed through restriction at 7837' & worked down to 7948'. POOH - found some lead on broach. RD Meyers. Circ through fish. RU Go WL & RIH w/ i 1/2" tools (sinker bar, jars, CCL). Tools stopped at 7948' - could not get deeper. POOH w/ WL. RIH w/ l" tools (sinker ar & CCL) - stopped at 7952'. Worked & pushed down to 7984'. POOH. RIH w/ I 3/8" spent jet cutter on sinker bars - hit 5" x 3 1/2" x O. POOH - cutter ok. RIH w/ i 3/8" spent cutter - stopped at 7945'- could get no deeper. POOH w/ WL. Pulled up to 260~ on DR - pkr would not jar loose. RIH w/ i 3/8" jet cutter - worked down to 2nd GLM at 8396'. Pulled up to 8377' & flred cutter, POOH w/ WL. Worked pipe up to 250M# & parted tbg. POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 5/26/83 11750' TD 10548' ETD (EST TOP OF L.S. FISH) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: ACC COST: $ 31,219 $ 479,589 AFE AMT: $ 940,000 POOH w/FTR #27. Recovered 569.44' of L.S. 2-3/8" tubing fish. (Top of L.S. $ 8379') Ran 5-3/4" O.S. w/ 2-3/8" Grapple (FTR #28). Engaged top of S.S. Fish $ 7833'. Circ. capacity of tubing & D.R. - OK - 400 psi. No fluid loss to FM. RU Meyers W.L. unit & ran 1-13/16" Broach - unable to get below 8013'. ROOH - RD W.L. Sarred fish 245M. R.U. A.R.R.S. 1-3/8" tubing cutter on GO Int W.L. unit & TIH. Tubing cutter stopped on GLM ® 10072 WLM. Logged collars & GLM in S.S. Rositioned cutter ~ 8534 (+ 20' above GLM 8 8554) Cut tu-bing & ROOH w/FTR #28. Recovered 701.53' of fish (Top of S.S. fish 8534') Ran 5-3/4" O.S. w/2-3/8" Grapple (FTR #29). Engaged top of L.S. fish 8 8379. Oarred Baker Model A-5 dual 2-3/8" packer 10521 free w/255M. (NOTE: Had cut L.S. tubing ® 10548 below packer previously.) 16 5/27/83 11750' ID 10547' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: ACC COST: $ 75,989 $ 555,578 AFE AMT: $ 940,000 POOH w/ dual tbg fish. Recovered 2043.62' of 2 3/8" SS including 63 jts, 5 pups, 5 GLM's, I cutoff, i xa & i "N" nipple, 2163.48' of 2 3/8" LS including 67 jts, 2 cutoffs, 3 pups, 7 GLM's & i "xa", & a 7" dual A-5 pkr. (Note: Rkr was missing btm slips). TOF estimated ~ 10548'. RIH w/ BHA #30 (cut-lip guide, 2 hollow mill extensions, OS bowl w/ 2 3/8" grapple, & top sub). Initially took wt e 7505' (possible pce of lead). RIH & rotated ® TOF ~ 10547'. Had high torquoe out could not latch onto fish. ROOH - rec large, ball of .203" WL (f/ SS gun) & 18" pce of 7/8" bar (f/ centralizer on LS jet cutter fish). RIH w/ BHA #31 (6"x5 1/4"x4 3/4" dressed shoe, 5 3/4" x 5" jt of washpipe, 2 3/8" hollow mill control, OS w/ 2 3/8" grapple, top sub). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 17 5/28/83 DAILY COST: ACC COST: AFE AMT: 18 5/29/83 DALLY COST: ACC COST: AFE AMT: 11750' TD 10547' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 26,824 $ 582,402 $ 940,000 11750' TD 10581' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW 26,194 608,596 $ 940,000 RIH w/ BHA #31. Worked over TOF ~ 10547' & rotated shoe to 10593' Had high torque. Latched onto ~ish but pulled off w/ 8OM# overpull. POOH - no rec. RIH w/ WL spear & 6" stop on DP to 10556'. Rotated spear & POOH - no rec (Note: 3 barbs on spear bent). RIH w/ BHA #33 (6" ro- tary shoe tapered to 3" ID, welded hollow mill control to 2 3/8", con- ventional hollow mill control to 2 3/8", OS bowl w/ 2 3/8" grapple) & latched onto fish ~ 10547'. Oarred on fish w/ 284M# (8OM# over normal pickup) - would not pull loose. RIH w/ 1 1/2" tools (broach, jars, sinker bars) - could not get into TOF ~ 10547'. POOH - left btm 2" of broach in hole. RIH w/ 1 3/8" jet cutter - could not get into TOF. POOH. Performed blind backoff while pulling 212M#. RIH w/ CCL to confirm backoff below grapple. POOH w/ WL. Completed POOH. Rec 29.03' of tbg including 1 cut-off & 2 pups. Found 2" broach tip in TOF. TOF now e 10572'. RIH w/ BHA #34 (5 3/4" guide, 5 3/4" x 2 3/4" short catch OS w/ grapple, top sub). Rotated over & latched onto fish ~ 10572'. RU ARRS & ran i 3/8" free pt indi- cator. Lost grapple hold once while freepointing. Found tbg 100% free 10664' & 100% stuck ® 10684' Ran CCL & found "XA" e 10572' ~ 7/8" blast jts f/ 10602' to 10724', & "XA" 8 10816' POOH. RIH w/ i 13/16" jet c~tter - stopped 10844'. Cut 2 3/8" tbg 8 10842' (above prod pkr ~ 10855'). Trip for i 13/16" jet cutter & cut tbg 10742' (15' below blast jts). Trip for i 13/16" jet cutter & cut tbg 10577' (below top "XA" sleeve). POOH w/ WL & rigged dwn ARRS. POOH w/ DR - rec 9.2' of fish including I cut-off & i "XA" sleeve. TOF 10581'. RIH w/ BHA #35 (5 3/4" cut-lip guide, 2 hollow mill extensions, OS bowl w/ 2 3/8" grapple, 1 top extension). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G--8 FIELD Mc3trthttr .River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 19 5/30/83 11750' TD 10597' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: ACC COST: $ 28,249 $ 636,845 AFE AMT: $ 940,000 RIH w/ BHA #35 & latched onto fish ~ 10581'. Attempted to circ-could not. gaffed on ifsh & tbg parted while jarring ~ 310M# (105M# over-pull). POOH & rec 15.30' of tbg. TOF ~ 10597'. RIH w/ BHA #36 (cutlip guide, OS bowl w/ 3 21/32" grapple, 5 top extensions). Rotated over TOF ~ 10597' Had high torque while rotating dwn] Had a hold of fish twice but pulled off w/ 80~; overpull. POOH-found guide chewed up & grapple untouched. RIH w/ BHA #37 (5 3/4" rotary shoe, 0S bowl w/ 3 21/32" grapple, 5 top extensions). Began to have torque ~ 10587'. Rotated & worked rotary shoe to 10605'. Could not get deeper. POOH - left btm 4.91' of BHA #37 on hole (rotary shoe, OS bowl, 1 top extension). There were marks on OD of top extensions 13' above twist off. RIH w/ BHA #38 (6" lead impression block, jars, 9 DC's). 20 5/31/83 11750' TD 10606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: ACC COST: $ 30,548 $ 667,393 AFE AMT: $ 940,000 Finished RIH w/ 6" Impression Block. Tagged TOF ~ 10593' & set 18M# on fish. POOH - IB showed 2 3/8" (necked down to 2 1/8") tbg stub up. RIH w/ BHA #39 (5 3/4" cut-lip guide, 5 3/4" OS bowl w/ 2 5/16" grapple, top sub) & latched onto fish ~ 10593'. Pulled 53M# opver normal pickup & made blink backoff. POOH & rec 13.46' of 2 3/8" tbg cut-off. Top or orig fish (2 3/8" x 2 7/8" XO) ~ 10606'. RIH w/ BHA #40 (2 3/4" x 5 3/4" taper tap, xo, B/S, oil jars, xo, 9 DC's) & rotated into lost fishing tools ~ 10603'. POOH & rec all lost fishing tools (rotary shoe, OS bowl, and top extension). RIH w/ BHA #41 (6" IB). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. lO LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 21 6/1/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 42,331 $ 709,724 $ 940,000 RIH w/ BHA #41 (6" Impression Block) & tagged TOF $ 10606'. Sat down on fish w/ 1SM# & ROOH. Rec 16 1/4" of of i 13/16" jet cutter & assembly imbedded in ID. Also had an impres- sion of a 1 7/16" rope socket look- ing up that was located i 1/8" in f/ outside edge. RIH w/ BHA #42 (4 1/8" short catch OS bowl w/ i 3/8" grapple, 4 1/8" top sub w/ decentralizing lug welded on side such that OD across lug is 5 13/16", xo, 2 7/8" pup-lO' long, xo, 3 1/2" pup-19' long). Tagged TOF 8 10606' but could not get over WL fish. POOH-no rec. Lip of OS appeared to have been running on 2 3/8" coupling on top of tbg fish. Worked & built on special rotary shoe. 22 6/2/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 26,269 $ 735,993 $ 940,000 RIH w/ BHA #43 (5 3/4" x 4 3/4" rotary shoe). Tools set down iOM# 8 lO600'. Rulled 5OM# over string wt to pick back up to 10585'; then came free. Picked up to 10573'. Rotated dwn limiting max torque to 350 amps. Rotated dwn to 10591' & had high torque. Picked back up to 10573' & rotated dwn again. Reamed dwn to 10608'. Reamed very slow thru interval f/ 10599' to lO601' & could not work dwn past 10608'. ROOH. Recovered a ball of junk WL inside rotary shoe, small amt of lead f/ IB & small pcs of packer junk. Make up BHA #44. 23 6/3/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 31 SEC KCL Brine $ 36,369 $ 772,362 $ 940,000 RIH w/ BHA #44 (5 3/4" x 4 3/4" rotary shoe & a jt wash pipe). Ran in to 10608' without seeing any obstructions. Washed over fish f/ 10608' to 10612'. ROOH. RIH w/ BHA #45 (5 3/4" OS bowl & 3 21/36" grapple). Engauged fish ® 10606'. Worked & jarred fish pulling +200 M over string wt. Ran ARRS sin~er bars in pipe tools set down ~ 10724' (x-over e btm of blast jts). ROOH. RIH w/ string shot & free pt. Determined fish to be stuck ~ grapple. Attempted to release grapple - could not release hold. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. ll LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 24 6~4~83 DAILY COST: ACC COST: AFE AMT: 25 6/5/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 11606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 9820' 7" L. 7396-11747' 65 PCF 31 SEC KCL Brine $ 27,479 $ 799,841 $ 940,000 11750' TD 10606' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 31 SEC $ 33,904 $ 833,745 $ 940,000 Shot APRS string shot 8 grapple & fired same. Grapple came free-POOH. RIH w/ BHA #46 (5 3/4" x 4 3/4" ro- tary shoe on 1 jt of washpipe). Took wt ~ 10601'. Washed over fish f/ 10601' to 10602' & came free. RI to 10613'. Washed over fish f/ 10613' to 10616'. Trip for new shoe & BHA #47. Went right back to 10616'. Washed over fish f/ 10616' to 10619'. (Note: Pump high vis sweeps as needed for cleaning). Washed over fish f/ 10619' to 10620'. Trip for new shoe & BHA #48. Washed over fish f/ 10620' to 10626'. Trip for new shoe & BHA #49. Washed over fish f/ 10626' to 10629'. (Note: Pumped high vis sweeps as needed. 26 6/6/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 66 PCF 33 SEC $ 36,410 $ 870,155 $ 940,000 POOH - shoe #5 was bald. RIH w/ shoe #6 on BHa #51 (WO shoe, 1 jt 5 3/4" washpipe, washover boot basket, xo, 2 boot baskets, bit sub, B/S, oil jars). Oad relatively high torque on btm - 500 amps. Washed over f/ 10629' to 10631'. Pulled up to 9 5/8" csg to shake off possible junk. RIH - had 500 amps w/ shoe @ 10605' ~ 44 RPM. POOH to check shoe. Shoe appeared ok. Changed out washpipe due to external cutting. RIH w/ shoe #7 on BHa #52 (same as #51). Rubbered DP on trip in. Reamed down f/ 10629' to 10631'. Washed over f/ 10631' to 10635'. Ran 120 bbl viscous gel sweeps periodically to clean btm of hole. Torque appeared to be decreasing. LEASE DATE SHEET D PAGE NO. 12 UNION OIL COMPANY OF CALIFORNIA WELL RECORD ADL #18730 ETD WELL NO. G-8 RD WO FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 27 6/7/83 DALLY COST: ACC COST: AFE ANT: 28 6/8/83 DAILY COST: ACC COST: AFE AMT: 29 6/9/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10630' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 67 PCF 34 SEC $ 35,112 $ 905,267 $ 940,000 11750' TD 10630' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 67 PCF 42 SEC $ 31,323 $ 936,590 $ 940,000 11750' TD 10630' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 67 PCF 42 SEC $ 30,456 $ 967,046 $ 940,000 Washed over & milled f/ 10635' to 10639'. POOH. RIH w/ BHA #52 (cut- lip guide, OS bowl w/ 3 21/32" grap- ple, 2 top extensions, top sub, etc) & engaged fish ~ lO610', guide ~ 10618'. Pulled 360M# (9OM# over normal pickup) & pulled loose. Ran down & guide went to 10622' (4' low- er than previously). Pulled loose w/ 4OM# overpull. RIH to 10622' & attempted blind baokoff - had indication of backoff in DP. POOH - found 5" DP loose 2 stds down. Tightened 5" DP. POOH - rec XO and i blast jt (20.55' OA). Blast jt appeared to part in threads. The btm 4' of blast jt had been milled flat on one side (to 3 1/4" OD) & apparently had been beside itself down hole. RIH w/ BHA #53 (6" x 4 3/4" rotary shoe, i jt of washpipe, washover boot basket, XO, 2 boot baskets). Worked over TOF ~ 10630' & WO f/ 10638' to 10641'. Pulled up & dragged junk up the hole. Remilled f/ 10638' to 10640'. POOH. Finished POOH. (Rotary was com- pletely bald). RIH w/ rotary shoe #9 on BHA #54 (same as #53). Reamed f/ 10639' to 10640' & milled f/ 10640' to 10642'. POOH. Shoe #9 was completely bald. RIH w/ rotary shoe #lC (6" x 4 3/4" 3 3/4" throat) on BHA #55 (same as #54). Washed over & milled f/ 10641' to 10645'. POOH - shoe was bald on btm & 70% worn in throat. There was a 1/4" groove on btm. RIH w/ rotary shoe #11 on BHA #56 (same as #55). Milled w/shoe #11 on BHA #56 F/10645' to 10652'. Trip for new shoe. With shoe #12 on BHA #57 milled F/10652' to 10658' and fell free RIH to 10663' (Bottomed out on wash pipe). Circ clean & POOH. RIH w/BHA #58 (o.s. w/3-21/32" grapple etc.). Engaged fish ~ 10630' without seeing pack off, picked up 1JT-No. indica- tion & fish. RU ARRS WL & RIH w/same 1-3/8" CCL & sinker bars. couldn't go thru grapple - indicating that have fish. LEASE ADL #18730 UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. G-8 RD WO SHEET D PAGE NO. 13 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 30 6/10/83 DAILY COST: ACC COST: AFE AMT: 11750' TO 10676' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 67 PCF 42 SEC $ 36,924 $1,003,970 $ 940,000 Pulled WL. POOH w/ DP. Recovered 1 blast jt 20.07' long & 20" poe 1 1/2" on top. RIH & engauged fish w/ fishing assy #59. Unable to jar fish loose. Blink backoff & POOH. Rec 1 full blast jt 20.00' long. RIH w/ fishing assy #60, retary shoe on wash pipe. Washed over fish ® 10676' & cleaned down to 10744'. Ciro clean. POOH. 31 6/11/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10864' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 66 PCF 46 SEC $ 103,257 $1,107,227 $ 940,000 RIH w/ fishing assy #61. Engauged fish ~ 10676' - POOH. Rec 74.60' of fish. RIH w/ fishing assy #62. En- guaged fish ~ 10750'. POOH. Rec 101.00' of fish. RIH w/ fishing assy #63 & engauged fish ~ 10851'. Pulled seal assy out of pkr. Circ clean. POOH. Rec entire seal assy to mule shoe. RIH w/ fishing assy #64 (pkr picker). 32 6/12/83 DALLY COST: ACC COST: AFE AMT: 11750' TD 11516' ETD (JUNK) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 44 SEC $ 27,127 $1,134,354 $ 940,000 RIH. Burn over perm pkr ~ 10864' in 1 hr & 50 min. POOH. Rec pkr. RIH w/ fishing assy #65 (concave junk mill). Tagged junk & fill ~ 11504'. Cleaned out f/ 11504-11514' & mill plugged. POOH. Test BORE to 3000 psi. RIH w/ fishing assy #66 (6 blade junk mill). Milled f/ 11514' to 11516'. 33 6/13/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 11516' ETD (JUNK) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 40 SEC $ 29,555 $1,163,909 $ 940,000 Circ well clean ~ 11516'. POOH. LD BHA #66 (junk mill #2). Cutting surf 100% gone. PU BHA #67 (globe basket w/ shoe mill & boot basket). Tagged junk ® llS16'-unable to rotate fishing tools below 11516'. POOH. Shoe on globe basket 100% worn out. No recovery. LD fishing tools. RU GO Int WL unit & ran Dialog 7" csg inspection log f/ 11450' to top 7" liner ~ 7396' POOH. RD WL Unit. Replace ~i clutch on drawworks drum. PU 6" concave mill & 7" csg scraper. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 34 6114183 DAILY COST: ACC COST: AFE AMT: 35 6/15/83 11750' TD 11516' ETD (JUNK) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 39 SEC $ 20,879 $1,184,788 $ 940,000 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine DAILY COST: $ 39,639 ACC COST: $1,223,822 AFE AMT: $ 940,000 36 6/16/83 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine DAILY COST: $ 64,235 ACC COST: $1,288,057 AFE AMT: $ 940,000 37 6/17/83 DAILY COST: ACC COST: AFE AMT: 38 6/18/83 DALLY COST: ACC COST: 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine $ 18,755 $1,306,812 $ 940,000 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine $ 18,865 $1,325,677 Ran 6" concave mill on 7" csg scrpr to 11516'. Had indication of re- striction in 7" from 10590' to 10600'. POOH. Ran 8 1/2" bit in 9 5/8" csg sorpr to TOL $ 7396'. POOH. Repaired elec line in draw- works "B" motor. Reran 6" mill & 7" csg scrpr to 11516' - did not see anything ~ 10590 to 10600'. POOH. RIH & set RTTS ~ 10500'. Press tstd 7" & 9 5/8" above 10500' to 1500 psi for 15 min w/ no leakoff. POOH. RIW w/ OEDP, fill DP w/ FIW & sand out to 11490'. X-over to new 6% kcl brine. Spot 50 bbl perf pill of 6% kcl w/ 2 1/2PPB "xc" & 21PPB CaC03 f/ 11490' to 10142'. POOH. Rigged up DA. Perfed HB #4 w/ 4 HPF using 4" csg guns f/ 11372' to 11402' & 11352' to 11372'. Perfed 4 HPF w/ GO Int 4" csg guns the following intvls:HB #4 f/ 11332' to 11352' & f/ 11294' to 11324'; HB #2 f/ 11102' to 11132'; HB #1 f/ 11058' to 11078'; G-3 sand f/ 10668' to 10708' & 6-2 sand f/ 10620' to 10645'. Ran WL GR to 11100'. Set Baker "F" pkr $ 10856' on WL. RIH w/ 2' of seals & test pkr ~ 10856' DIL. Tagged pkr ~ 10877' DPM & tstd same to 650 psi. POOH laying down DP. Changed pipe rams dual 2 3/8" lower & 3 1/2" x 2 7/8" in middle. RU to run dual completion assembly. Ran dual comp assy w/ 2 3/8"x2 3/8" dual in 7" liner & 3 1/2"x2 7/8" dual in 9 5/8" csg. Had 105M# down wt & 155M# up wt prior to lndg tbg. Tstd LS seals in perm pkr ~ 10856'. RU Meyers WL. & set "XN" plug in LS ~ 10921'. AFE AMT: $ 940,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 15 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 39 6/19/83 , 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine DAILY COST: $ 316,244 ACC COST: $1,641,921 AFE AMT: $ 940,000 40 6/20/83 DAILY COST: ACC COST: AFE AMT: 41 6/21/83 DAILY COST: ACC COST: AFE AMT: 42 6/24/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' $ 18,755 $1,660,676 $ 940,000 11750 ' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' $ 17,237 $1,677,913 $ 940,000 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' $ 19,657 $1,697,570 $ 940,000 Set & tested Baker "A-5L" dual pkr 10488' w/ 1000 psi down annulus. (NOTE: Ran SS w/ dummy GLV's in mandrels). Rulled "XN" plug nipple ® 10921'. Slacked off 2' & landed tbg in tbg spool. Opened btm XA in LS ~ 10834'. Installed BRV's, re- moved BORE, installed & tested dual CIW tree. Move rig to leg room #3 while unloading G-8 RD. Released rig to AFE # 331402 G-3 RD ® 24:00 hrs, 6/21/83 for naphtha & FFA-I treatment. RU over G-8 RD WO for acid job on "G" zone perfs. Offloaded acid onto Grayling Rlatform. RU Dowell & di- luted acid toproper concentrations. Bled gas lift press off of ann. RU Myers WL on LS & RIH w/ "XN" plug- could not get below 10845' ROOH. RIH w/ shifting tool & clo~ed "XA" sleeve @ 10834'. ROOH. RIH w/ "XN" plug & set plug in "XN" nipple ~ 10922'. ROOH. RIH w/ shifting tool & opened "XA" sleeve in LS ~ 10834'. ROOH & RD Myers WL. Tstd surf lines to 5000 psi. Displ 57 bbis of 7 1/2% HCL w/ .5% A-200, ,4% F-75N,.2% 0-237, .2% W35, .4% L53W, and 65 lbs L-41/lO00 gal down SS while taking fluid returns up LS. Discovered that HCL was contaminated w/ a greasy substance. RU myers WL & closed "XA" sleeve in LS ~ 10834'. Sent sample of HCL to lab to be analyzed. Filled annulus in TBUS G-27 while waiting on analysis of acid. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 16 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS ~3 6/25/83 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' DAILY COST: ACC COST: $ 28,325 $1,725,895 AFE AMT: $ 940,000 RIH in LS & opened "XA" sleeve ~ 10834'. Pumped down LS & out SS to remove contaminated acid f/ tbg. - Sent new 7 1/2% HCL mix out to Grayling. Displ SS w/ 52 bbls of 7 1/2% HCL w/ .6% A-200, .4% L53W, and 65 lbs L-41/lO00 gal. Closed "XA" sleeve in LS 8 10834'. POOH sleeve ® 10834'. POOH w/ WL. Pumped additional 20 bbls 7 1/2% HCL mix followed by 100 bbls of 6 1/2% mud acid w/ additives. Observed pressure on LS & annulus increase to 2200 psi while pumping in SS w/ 2 1/2BRM 8 2500-3000 psi. Shut-in SS. Pressure on SS fell to 0 psi while the pressure on LS & annulus remained e 2200 psi. Bled annulus pressure to 1000 psi (all gas) & LS pressure dropped to 1400 psi. RIH in LS & confirmed all "XA" sleeves closed. POOH w/ WL. Continued w/ acid job. Pumped 55 more bbls of mud acid followed by 15 bbls of 3% NH4CL spacer ~ I BRM w/ 2500 psi. Pumped 155 bbls of clay acid w/ additives followed by l0 bbls of diesel w/ 10% U-66. Displ acid w/ 31 bbls of diesel. Shut-in well for 8 hrs. Released rig f/ G-8 hRD WO to TBUS G-27 WO ~ 24:00 hrs. TUBING DETAIL ~onfl 1. ~ 1/2" Otis ball valve 324' '2. 3 1/2" McMurry - Hughes GLM 2587' 3. 3 1/2" McMurry - Hughes GLM 4200' 4. 3 1/2" McMurry - Hughes GLM 5584' 5. 3 1/2" McMurry - Hughes GLM 6022' 6. 2 3/8" Camco GLM 7551' 7. 2 3/8" Camco GLM 8132' 8. 2 3/8" Camco GLM 8626' 9. 2 3/8" Camco GLH 8995' lO. 2 3/8" Camco GLH 9340' Il. 2 3/8" Camco GLH 9678' 12. 2 3/8" Camco GLM 10013' 13. 2 3/8" Camco GLM 10~31' 14. 2 3/8" Otis "XA" 10455' 15. 7" A-5 Dual RKR 10488' 16. 2 3/8" Otis "XA" 10563' 17. 2 7/8" Blast joints 10626'-10744' 18. 2 3/8" Otis "XA" 10834' 19. Locator 10874' 20. Seal Assembly 10875'-10891' 21. Otis "XN" 10922' 22. 2 3/8" Mule shoe 10951' Short Strinq3' A. 2 7/8" Otis ball valve 357' B. 2 7/8" MACCO GLM 2519' C. 2 7/8" MACCO GLM 4414' D. 2 7/8" CAMCO GLM 6008' E. 2 7/8" CAMCO GLM 7297' O. 2 3/8" McMurry - Hughes GLM 8400' G. 2 3/8" CAMCO GLM 9207' H. 2 3/8" Otis GLM 9645' I. 2 3/8" Otis GLM 10079' O. 2 3/8" Otis GLM 10301' K. 2 3/8" Otis "XA" 10425' t. 2 3/8" Otis "XN" 10563' 15 7" TOP ~ 7396' 9 5/8" C. 7820' G-3 10620' - 10645' G-4 10668' - 10708' HB #1 11058' - 11078' 22 · HB #2 11102' - 11132' HB #4 11294' - 11324' 11332' - 11402' TBUS G-SWO Begun 5/12/83 Completed U,N~ON OIL CO~'~',AN"~ 0~ C,~L~F~"~I"N~I,A I II 6/25/83 i i 7" C. 11747' AI."'D. _ sc~_ ~ia o,~ _ 9/15/8,,3' --. SH"EI$ ~ %~EEl DCB Form D-lOO1-A UNION OIL CO. OF CALIFORNIA REPAIR RECORD LEASE Trading Bay Unit WELL NO. G-8 WO FIELD IMoArthur 'River Field BEGAN 5/12/83 COMPLETED 6/25/83 PERMIT NO. 78-45 SERIAL NO. ADL 18730 COMPANY ENGINEER Grahams. McAllister~ Abernathy~ Bush APPROVED SHEET A Page No. 1 CONTRACTOR Conservative Drill. lng Company. TYPE UNIT 'Nationa'l 1320 UE CASING HEAD ':~, ELEVATIONS: GROUND TUBING HEAD ROTARY DRIVE BUSHING 99' MLLWv CASING & TUBING RECORD SIZE DEPTH WEIGHT GRADE REMARKS 20" 358' 1/2" Wall Drive 16" 589' 75# J-55 13 3/8" 3103' 61# 0-55 9 5/8" 7820' 43.5# N-80 7" 11747' to 29# N-80 7396' Pipe Cmtd w/ 1200 sxs cmt Cmtd w/ 2300 sxs cmt Cmtd thru shoe w/ 1500 sxs & thru DU w/ 1800 sx Cmtd w/ 830 sxs PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 8/3/78 11264' to 11266' 11623' 8/8/78 10668' to 10708' 11230' 8/9/78 10620' to 10645' 11230' 8/12/78 11294' to 11324' 11623~ 8/12/78 11332' to 11402' 11623' 8/13/78 10668' to 10708' 11623' 1/30/79 11430' to 11432' 11623' 2/2/79 11264' to 11266' 11285' 2/8/79 11332' to 11402' 11263' BS #1 Production Production Production Production Production BS BS Production Squeezed w/ 100 sxs cmt G-4 - Open G-3 - Open Hemlock Bench #4 - Open Hemlock Bench #4 - Open Reperf G-4 - Open Squeezed w/ 150 sxs Squeezed w/ 250 sxs Reperf H.B. #4 - Open INITIAL PRODUCTION AFTER REPAIR DATE INTERVAL NET OIL CUT GRAV. C.R. T.R. CHOKE MCF GOR REMARKS WELL HISTORY PRIOR TO REPAIR COMPLETION DATE: 12/20/79 LAST COMPLETION NO. 2 PRODUCING INTERVAL: INITIAL PRODUCTION: LAST REGULAR PROD. & DATE: CUMULATIVE PRODUCTION: REASON FOR REPAIR: To reperf "G" zone and acidize same. Also~ to recover wireline fish left in hole. ., fora D-IOO1-B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B 2 PAGE NO. LEASE Tradin. g. Bay Unit COMPL'~FI'ON' "DATE 6/25/83' WELL NO. G-8 WO FIELD McArthur River Field APPROVED .... D'ATE iNTERVAL ETD REASON PRESENT CONDITION 2/09/79 11324' to 11294' 11623' Production 2/09/79 11668' to 10708' 11623' Production 2/09/79 10620' to 10645' 11623' Production 6/15/83 11352' to 11402' 11490' Production 6/16/83 11332' to 11352' 11490' Production 6/16/83 11294' to 11324' 11490' Production 6/16/83 11102' to 11132' 11490' Production 6/16/83 11058' to 11078' 11490' Production 6/16/83 10668' to 10708' 11490' Production 6/16/83 10620' to 10645' 11490' Production Hemlock Bench #4 - Open G-4 - Open G-3 - Open H.B. #4 Reperf - Open H.B. #4 Reperf - Open H.B. #4 Reperf - Open H.B. #2- Open H.B. #1 - Open G-4 Reperf - Open G-3 Reperf - Open WELL HEAD ASSEMBLY TYPE- Cameron Iron Works CASING HEAD' Schaffer KD 12" 3000 psi w/ 2" Cameron Valves SOW 13 3/8" CASING HANGER: Schaffer KD 12" - 9 5/8" Model KD - KS Slips CASING SPOOL' TUBING HEAD' Cameron DC-B 12" 3000 psi x 10" 5000 psi TUBING HANGER- Dual Cameron 3 1/2" TUBING HEAD TOP' 3 1/2" EUE MASTER VALVES' CHP~ISTMAS TREE TOP CONN.' 3 1/2" EUE NOTE' The DC-B spool need work - the tie-downs ~,~ere very difficult to operate. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT WELL NO. G-8 WO FIELD MC ARTHUR RIVER FIELD TUBING DETAIL-LONG STRING 3TS 2 11 6 6 12 12 DESCRIPTION LENGTH 2 3/8" Mule Shoe 2 3/8" 4.6# N-80 Butt 2 3/8" Otis "XN" Nipple 2 3/8" 4.6# N-80 Butt 2 3/8" x 3 1/2" X.O. Baker Seal Assembly .69' 27.83' .55' 30.00' .86' 15.89' 9 5/8" Baker "F-I" Packer $ 10,856' DIL, 10,877' DPM Baker Locator 3 1/2" x 2 3/8" X.O. 2 3/8" Pup 2 3/8" 4.6# N-80 Butt 2 3/8" Otis "XA" Sleeve 2 3/8" 4.6# N-80 Butt 2 3/8" x 2 7/8" X.O. 2 7/8" Blast Joints (3.688" O.D.) 2 7/8" x 2 3/8" X.O. 2 3/8" 4.6# N-80 Butt 2 3/8" Otis "XA" Sleeve 2 3/8" 4.6# N-80 Butt 2 3/8" Butt x 8rd X.O. Baker AL-5 Dual Packer 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Otis "XA" Sleeve 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups (2) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM'"(2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Cemco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups (2) .84' .89' 5.12' 31.44' 2.58' 89.37' .74' 118.00' .76' 60.07' 2.50' 62.47' 1.20' 10.58' 30.67' 2.55' 118.61' 6.10' 178.55' 6.10' 58.15' 7.06' 61.75' 6.08' 328.23' 6.11' 179.20' 5.02' 148.02' 6.50' 57.25' 5.08' 58.84' 4.07' 30.05' 5.13' 178.12' 5.78' 364.13' 5.79' 211.67' 8.18' 267.49' 5.80' 209.49' 4.08' 361.36' 6.12' 242.88' 8.59' BTM _ 10,950.82' 10,950.13' 10,922.30' 10,921.75' 10,891.75' 10,890.89' 10,875.00' 10,874.16' 10,873.27' 10,868.15 10,836.71' 10,834.13' 10,744.76' 10,744.02' 10,626.02' 10,625.26' 10,565.19' 10,562.69' 10,500.20' 10,499.02' 10,488.44' 10,457.77' 10,455.22' 10,336.61' 10,330.51' 10,151.96' 10,145.86' 10,087.71' 10,080.65' 10,018.90' 10,012.82' 9,684.59' 9,678.48' 9,499.28' 9,494.26' 9,346.24' 9,339.74' 9,282.49' 9,277.41' 9,218.57' 9,214.50' 9,184.45' 9,179.32' 9,001.20' 8,995.42' 8,631.29' 8,625.50' 8,413.83' 8,405.65' 8,138.16' 8,132.36' 7,922.87' 7,918.79' 7,557.13' 7,551.31' 7,308.43' TOP 10,950.13' 10,922.30' 10,921.75' 10,891.75' 10,890.89' 10,875.00' 10,874.16' 10,873.27' 10,868.15' 10,836.71' 10,834.13' 10,744.76' 10,744.02' 10,626.02' 10,625.26' 10,565.19' 10,562.69' 10,500.22' 10,499.02' 10,488.44' 10,457.77' 10,455.22' 10,336.61' 10,330.51' 10,151.96' 10,145.86' 10,087.71' 10,080.65' 10,018.90' 10,012.82' 9,684.59' 9,678.48' 9,499.28' 9,494.26' 9,346.24' 9,339.74' 9,282.49' 9,277.41' 9,218.57' 9,214.50' 9,184.45' 9,179.32' 9,001.20' 8,995.42' 8,631.29' 8,625.50' 8,413.83' 8,405.65' 8,138.16' 8,132.36' 7,922.87' 7,918.79' 7,557.43' 7,551.31' 7,308.43' 7,299.84' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO, ,. LEASE TRADING BAY UNIT WELL NO. G-8 WO FIELD MC ARTHUR RIVER FIELD TUBING DETAIL-LONG STRING JTS 19 23 10 12 4 3 10 18 6 12 2O 2O DESCRIPTION 2 3/8" x 3 1/2" X.O. 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurry-Hughes MHO GLM (4 1/8" FN) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurry-Hughes MHO GLM (4 1/8" FN) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" McMurry-Hughes MHO GLM (4 1/8" FN) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" MoMurry-Hughes MHO GLM (4 1/8" FN) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pup 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Otis Ball Valve 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pups (4) " CIW Dual Tubing Hanger Landed Below R.T. LENGTH .43' 571.09' 6.22' 701.16' 6.10' 119.05' 4.80' 300.81' 6.30' 358.25' 5.10' 117.91' 5.14' 208.65' 4.07' 208.61' 5.10' 242.57' 5.15' 119.25' 4.90' 92.95' 6.25' 297.47' 5.11' 542.63' 5.10' 236.79' 5.03' 270.20' 5.12' 239.09' 6.20' 60.40' 5.08' 178.39' 5.02' 359.44' 5.00' 61.99' 8.62' 596.69' 4.83' 604.81' 4.85' 147.67' 4.81' 213.23' 2.23' 272.85' 13.50' 1.00' 36.83' BTM 7,299.84' 7,299.41' 6,728.32' 6,722.10' 6,020.94' 6,014.84' 5,895.79' 5,890.99' 5,590.18' 5,583.88' 5,225.63' 5,220.53' 5,102.62' 5,097.48' 4,888.83' 4,884.76' 4,676.15' 4,671.05' 4,428.48' 4,423.33' 4,304.08' 4,299.18' 4,206.23' 4,199.98' 3,902.51' 3,897.40' 3,354.77' 3,349.67' 3,112.88' 3,107.85' 2,837.65' 2,832.53' 2,593.44' 2,587.24' 2,526.84' 2,521.76' 2,343.37' 2,338.35' 1,978.91' 1,973.91' 1,911.92' 1,903.30' 1,306.61' 1,301.78' 696.97' 692.12' 544.45' 539.64' 326.41' 324.18' 51.33' 37.83' 36.83' TOP 7,299.41' 6,728.32' 6,722.10' 6,020.94' 6,014.84' 5,895.79' 5,890.99' 5,590.18' 5,583.88' 5,225.63' 5,220.53' 5,102.62' 5,097.48' 4,888.83' 4,884.76' 4,676.15' 4,671.05' 4,428.48' 4,423.33' 4,304.08' 4,299.18' 4,206.23' 4,199.98' 3,902.51' 3,897.40' 3,354.77' 3,349.67' 3,112.88' 3,107.85' 2,837.65' 2,832.53' 2,593.44' 2,587.24' 2,526.84' 2,521.76' 2,343.37' 2,338.35 ' 1,978.91' 1,973.91' 1,911.92' 1,903.30' 1,306.61' 1,301.78' 696.97' 692.12' 544.45' 539.64' 326.41' 324.18' 51.33' 37.83' 36.83' LEASE TRADING BAY UNIT UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-8 WO SHEET D 5 PAGE NO. FIELD MC ARTHUR RIVER FIELD TUBING DETAIL-SHORT STRING OTS 2 10 4 9 14 42 52 55 71 DESCRIRTION 2 3/8" Coupling 2 3/8" Otis "XN" 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Butt to 8rd X.O. Baker AL-5 Dual Packer 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Otis "XA" Sleeve 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Otis RW-4 GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg ,, 2 3/8" Otis RW-4 GLM (2 7/8 FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbq 2 3/8" Otis RW-4 GLM (2 ~/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Camco XBMG GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pup 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" McMurry-Hughes MHO GLM (2 7/8" FN) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups (2) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" Pups (2) 2 3/8" 4.6# N-80 Butt Tbg 2 3/8" x 2 7/8" X.O. 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Camco XBMG GLM (3 1/2" FN) 2 7/8" 6.4# N-80 Butt Tbg ,, 2 7/8" Camco XBMG GLM (3 1/2 FN) 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" MACCO GLM (3 1/2" FN) 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" Pup 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" MACCO GLM (3 1/2" FN) 2 7/8" 6.4# N-80 Butt"Tbg 2 7/8" Otis Ball Valve 2 7/8" 6.4# N-80 Butt Tbg 2 7/8" x 3 1/2" X.O. 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Pups (4) CIW Dual Tubing Hanger Landed below R.T. LENGTH .72' .58' 60.77' .87' 9.48' 6.08' 57.83' 2.55' 119.04' 5.68' 215.90 ' 5.78' 57.96' 6.08' 117.73' 5.12' 176.71 ' 5.10' 59.10' 5.80' 304.20' 5.00' 122.58' 6.12' 242.52' 4.07' 118.64' 5.05' 209.48' 5.04' 29.12' 4.06' 182.10' 7.64' 267.81' 7.18' 419.64' 3.94' 149.11' 7.18' 209.84' .43' 31.37' 5.84' 1,283.91' 5.87' 1,587.15' 6.16' 214.41' 5.11' 1,670.03' 6.13' 2,159.61' 1.98' 212.89' .39' 89.96' 13.75' 1.00' 38.94' BTM 10,'5~4.13' 10,563.41' 10,562.83' 10,502.06' 10,501.19' 10,491.71' 10,485.63' 10,427.80' 10,425.25' 10,306.21' 10,300.53' 10,084.63' 10,078.85' 10,020.89' 10,014.81' 9,897.08' 9,891.96' 9,715.25' 9,710.15' 9,651.05' 9,645.25' 9,341.05' 9,336.05' 9,213.47' 9,207.35' 8,964.83' 8,960.76' 8,842.12' 8,837.07' 8,627.59' 8,622.55' 8,593.43' 8,589.37' 8,407.27' 8,399.63' 8,131.82' 8,124.64' 7,705.00' 7,701.06' 7,551.95' 7,544.77' 7,334.93' 7,334.50' 7,303.13' 7,297.29' 6,013.38' 6,007.51' 4,420.36' 4,414.20' 4,199.79' 4,194.68' 2,524.65' 2,518.52' 358.91' 356.93' 144.04' 143.65' 53.69' 39.94' 38.94' TOP 10,563.41' 10,562.83'~ 10,502.06' 10,501.19' 10,491.71' 10,485.63' 10,427.80' 10,425.25' 10,306.21' 10,300.53' 10,084.63' 10,078.85' 10,020.89' 10,014.81' 9,897.08' 9,891.96' 9,715.25' 9,710.15' 9,651.05' 9,645.25' 9,341.05' 9,336.05' 9,213.47' 9,207.35' 8,964.83' 8,960.76' 8,842.12' 8,837.07' 8,627.59' 8,622.55' 8,593.43' 8,589.37' 8,407.27' 8,399.63' 8,131.82' 8,124.64' 7,705.00' 7,701.06' 7,551.95' 7,544.77' 7,334.93' 7,334.50' 7,303.13' 7,297.29' 6,013.38' 6,007.51' 4,420.36' 4,414.20' 4,199.79' 4,194.68' 2,524.65' 2,518.52' 358.91' 356.93' 144.04' 143.65' 53.69' 39.94' 38.94' Lonq 1. 3 1/2" Otis bail valve 324' '2. 3 1/2" McMurry - Hughes GLH 2587' 3. 3 1/2" McMurry - Hughes GLH 4200' 4. 3 1/2" McMurry - Hughes GLH 5584' 5. 3 1/2" McMurry - Hughes GLM 6022' 6. 2 3/8" Camco GLH - 7551' 7. 2 3/8" Camco GLM 8132' 8. 2 3/8" Camco GLH 8626' 9. 2 3/8" Camco GLH 8995' 10. 2 3/8" Camco GLH 9340' 11. 2 3/8" Camco GLH 9678' 12. 2 3/8" Camco GLM 10013' 13. 2 3/8" Camco GLH 14. 2 3/8" Otis "XA" 10455' 15. 7" A-5 Dual RKR 10488' 16. 2 ~/8" Otis "XA" 1056~' 17. 2 7/8" Blast joints 10626'-10744' 18. 2 3/8" Otis "XA" 108~4' 19. Locator 10874' 20. Seal Assembly 10875'-10891' 21. Otis "XN" 10922' 22. 2 3/8" Mule shoe 10951' Short Strinq.:. A. 2 7/8" Otis ball valve 357' E. 2 7/8" MACCO GLM 2519' C. 2 7/8" HACCO GLH 4414' D. 2 7/8" CAMCO GLM 6008' E. 2 7/8" CAMCO GLH 7297' D. 2 3/8" McMurry - Hughes GLM 8400' G. 2 3/8" CAMCO GLH 9207' H. 2 3/8" Otis GLH 9645' I. 2 3/8" Otis GLH 10079' J. 2 3/8" Otis GLM 10301' K. 2 3/8" Otis "XA" 10425' L. 2 3/8" Otis "XN" 10563' 13 3/8" C. 3103' 7" TOP $ 7396' 9 5/8" C. 7820' G-3 10620' - 10645' G-4 10668' - 10708' l~Y. [,, , ! i FORM 247 (Ni~W 5,~(~) 22 HB #1 11058' - 11078' 'HB #2 11102' - 11132' HB #4 11294' - 11324' 11332' - 11402' i ii i i iii i TBUS G-8WO Begun 5/12/83 Completed UNION OIL COMPANY OF CALIFORNIA 7" C. 11747' AI'P'O. o~ 9/15/83, 6/25/83 ,, UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 5112/83 11750' TD. 11600' ETD (Junk) 26" C. 350' 16" C. 590' 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' FIW DAILY COST: $ 38,060 ACC COST: ~ $ 38,060 AFE AMT: $ 940,000 2 5113183 11750' TD 11600' ETD (Sunk) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' FIW DAILY COST: $ 33,634 ACC COST: $ 71,694 AFE AMT: $ 940,000 5114183 11705' TD 11600' ETD (OUNK) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: $ 37,654 ACC COST: $ 109,348 AFE AMT: $ 940,000 Commenced operation~ 00:01 hrs 5/12/83. Bled press off LS & SS & 9 5/8" csg. Well is dead but has not been filled w/ fluid. RU Myers WL on SS. Pulled ball valve. RIH w/ impression block & tagged WL. Fish & drop bar top ~ 572'. Moved Myers to LS. RIH & pulled ball valve on Myers. RU Go 7/16" WL w/ 2 5/16" OS dressed w/ 1 1/2".grapple spang jars, oil jars & 15' of 1 1/2" sinker bar. RIH"tn SS. Engauged fish & Jarred top drop bas out (8 hrs). Markings indicate it had been driven past the top of the second bar. Attempted to fish 2nd drop bar in SS $ 580'- could not stay latched onto fish. Opened "XA" sleeve in LS · 10483'. Attempted to open "XA" in LS ~ 10817' but stuck shifting tool $10755'. Worked tools free & RD WL. Pumped dwn LS & up annulus w/ kcl fluid - recovered +300 bbls of oil. SS began to flow-due to under- balance. Took returns Out SS while pumping dwn LS to fill SS w/ kc1 fluid. Installled BPV's, removed tree, installed & tested BOPE. Mixed & pumped l0 F3 of Cal-Seal slurry dwn SS to lock-up WL. Cal-Seal slurry began setting up in lines. Pumped dwn LS & up SS to clear tbg. RU Go WL over LS & RIH w/ i ll/16" tbg cutter. Cut LS $ 10548' tbg meas (10565' ~LM). RD Go WL. Mixed & pumped l0 F~ of Cal-Seal'slurry dwn SS & displ w/ 2 7/8" tbg plug to top of fish ~ 580'. Attempted to release A-5 pkr by pulling on LS - pkr would not release. RU Go WL on SS & RIH w/ 2 1/4" tbg cutter. Tagged tbg plug $ 576' WLM. Pulled up & made cut in SS $ 540' WLM (537' tbg meas). POOH w/ SS. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE WELL NO. FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5/15/83 DAILY COST: ACC COST: AFE AMT: 5 5/16/83 DAILY COST: ACC COST: AFE AMT: 6 5117/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 7671' ETD (TOp of LS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW 27,451 136,799 $ 940,000 11750' TD 7671' ETD (TOp of LS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 27,330 $ 164,129 $ 940,000 11750' TD 7671' ETD (Top of LS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 27,635 $ 191,764 $ 940,000 Pulled & LD SS f/ 537'. RU Go WL on LS & RIH w/ 1 13/16" tbg cutter. Cutter stuck $ 7647' WLM (top GLM in 2 3/8" tbg). Could not free cutter. Mad cut & pulled WL out of rope socket leaving cutter in hole. Circ clean & POOH laying dwn LS f/ cut $ 7671' tbg maas. RIH w/ OS & tagged SS fish ~ 537' - could not latch onto fish. POOH - found hollow mill improperly dressed. Redressed mill & RIH - could not latch onto fish. POOH & chgd hollow mill insert. RIH - could not latch onto fish. POOH. RIH w/ new grapple in OS & latched onto fish $ 537'. Made blind back-off. POOH & LD tbg & broken sections of WL. Pulled & LD 2 7/8" tbg f/ SS. Rec 6535' of 2 7/8" tbg, 1 sinker bar, 1 Kinley cutter, & +_350' of WL. In- stalled 5" rams. RIH w/ WL spear on 5" DR. Rotated & picked up every 7 stds below 3000' Spear stopped ® 5526'. Rotated ~ picked up 2OM# overweight to pull loose. POOH. Reeled off 5300' of WL & cut + 3000' of wire off spear (total recovered of +9400'). Installed 2 3/8" rams & repaired se~ls in hinge on single gate. Repaired adjustment knob on drum brake. RIH w/ WL spear & 8 1/2" stop on 5" DP. Rotated & picked up 6000', 6500' & 7050'. Ran in to 7072' (top of SS). Picked up 2' & rotated. POOH. POOH w/ WL spear-had no recovery. RIH w/ OS cut-lip guide & screw-in sub to 7072'. Got over tbg but un- able to screw into top. POOH-screw- in sub was flared out. RIH w/ 8 1/2" impression block on DP to 7072'. Spudded down on top of SS to make impression. POOH - left entire lead portion in hole (IB was incorrectly made). RIH w/ 8 1/2"x7 1/2" rotary shoe & extension & RIH. Tagged fish $ 7067'. Rotated & pushed f/ 7067' to 7079'. POOH & rec small pce of lead. RIH w/ 8 1/2" guide, hollow mill control, OS w/ 2 7/8" grapple, & top extension to 7072'. Dressed tbg top & turned 33 1/2 turns to the right to make up any loose jts. Pulled 19OM# & grapple held. Picked up to remove kelly & grapple cam eloose w/ 20OM# upstrain (150M# is normal pickup). POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 7 5/18/83 DAILY COST: ACC COST: AFE AMT: 8 5/19/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 7671' ETD (Top of LS) 7680' ETD (TOp of SS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 31,907 $ 223,671 $ 940,000 11750' ID 7671' ETD (Top of LS) 7680' ETD (TOp of SS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 29,321 $ 252,992 $ 940,00n POOH w/ fishing tools & rec a 2"x3" pce of lead & a short section of 2 7/8" SC coupling. Chgd grapple & added i more top extension. RIH & latched onto SS ~ 7072'. Rulled up to 3OM# over normal RU. RU Go WL & RIH w/ i ll/16" tbg cutter on WL- would not go below 7068' WLM. ROOH w/ WL. Rulled up to 230M# (8OM# over normal pickup) on tbg & pulled loose. ROOH & rec + 1/2 of a SC 2 7/8" coupling w~ich was packed full of lead. Changed out grapples & RIH. Latched onto SS ~ 7072' & RU Go WL. RIH w/ i ll/16" tbg cutter-could not get past 7065' WLM. ROOH w/ WL. Rulled up to 30OM# on tbg & parted same. ROOH & rec 280.96' of 2 7/8" tbg & 327.26' of 2 3/8" tbg (608.22' total). Top of tubing was open and clear w/ no junk or bent tops. Top of SS now e +7680'. RIH w/ OS & 2 3/8" grapple t--o fish for LS ® &671'. Tagged junk ® 7401'. Rotated & pushed junk to 7676'. Milled on junk ~ 7676'. POOH - rec small amt of lead f/ OS. RIH w/ 6"x3 1/2" rotary shoe to 7676' DPM. Rotated & milled f/ 7676' to 7685' DPM. POOH-marks showed possibly 2 fish in hole. RIH w/ cut-lip guide, 2 3/8" hollow mill control, & OS w/ 2 3/8" grapple-could not get over fish ~ 7676'. POOH. Changed rams to dual 2 3/8" & changed seals in single gate. RIH w/ 4 5/8" short catch OS for run #16. Rotated over fish. Latched onto fish & pulled loose w/ 2OM#. Pooh-markings indicated 2 fish. RIH w/ 4 1/2" x 2 3/8" rotary shoe & OS w/ 2 3/8" grapple. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #1873O WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 5/20/83 DAILY COST: ACC COST: AFE AMT: 10 5/21/83 11750' TD 7684' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 30,091 $ 283,083 $ 940,000 11750' TD 7684' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: $ 31,569 ACC COST: $ 314,652 AFE AMT: $ 940,000 RIH w/ BHA #17 (4 1/2" x 2 3/8" ro- tary shoe w/ OS & 2 3/8" grapple). Rotated & milled over TOF ~ 7676'. Latched onto fish & pulled loose w/ 2OM# pull over string wt. POOH-rec 4.85' of LS & +12' of slivered SS which was corkscrewed around LS. RIH w/ BHA #18 (4" OD RH die collar) to TOF $ 7681'. Rotated over fish 12 turns when came loose. ROOH-rec 3 small (8" max length) pieces of tbg. RIH w/ BHA #19 (4 1/16" RH die collar) & engauged fish ~ 7684'. Screwed onto fish but pulled off w/ lOM# over pull. Re-engauged fish & attempted blind backoff-just unscrewed die collar. Re-engauged fish a 3rd time & jarred up to 9OM# over string weight-pulled free. POOH-no recovery. RIH w/ BHA #20 (4 3/4" LH die collar). Rotated onto fish ~ 7684' & made blind backoff. POOH - rec 55.50' of 2 3/8" tbg w/ pin dwn. Top of this fish is a coupling ~ 7740'. RIH w/ BHA #21 (5 7/8" external tbg cutter on 5 3/4" washpipe). Worked over TOF $ 7684' & located coupling ~ 7706'. Attempted outsaide cut ~ 7709'-no good. POOH-flipper dogs worn out Replaced burned out motor on draw- works. RIH w/ BHA #22 (4" external tbg cutter on 4" washpipe). Located coupling ~ 7706' & attempted outside cut ~ 7708'. POOH - had no recovery. Found 2 flipper dogs gone & 3 worn thru while i cutter was broken. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET O PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11 5/22/83 DAILY COST: ACC COST: AFE AMT: 12 5/23/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 7708' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 40,796 $ 355,448 $ 940,000 11750' TD 7740' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 33,793 $ 389,241 $ 940,000 Tested BOPE. RIH w/ BHA #23 (5 3/4" cut-lip guide, 2 3/8" hollow mill control extension, OS w/ 2 3/8" grapple, & 5.5' of top extension). Latch onto fish ~ 7684'. RIH w/ 1 7/16" sinker bar on WL - could not get below TOF ~ 7684'. POOH w/ WL. Pulled 7OM# over string wt & pulled loose. POOH - rec 24' of 2 3/8" tbg f/ cut ~ 7708'. RIH w/ BHA #24(same as #23 w/o top extension) to 7708' Latched onto fish & RIH w/ 1 13/16" broach on 1 1/2" sinker bar & spang jars on Myers WL. Worked into TOF ~ 7708' & RIH to 7834'-could not work any deeper. Pulled back up to TOF ~ 7708' & worked thru several times - ok. POOH & RD Myers. RU Go WL & RIH w/ i 13/16" jet cutter to 7836'. POOH w/ WL. Pulled up to 240M# on tbg - did not pull loose. RIH w/ jet cutter. Pulled 82M# over string wt & cut tbg ® 7810' WLM. POOH w/ WL - WL tools hung up in fishing tools ~ 7708'. Strip out of hole w/ WL & 1 13/16" tbg cutter. Rec 102.27' of 2 3/8" tbg f/ cut ~ 7810' & WL tools. RIH w/ BHA #25 (cut-lip guide, btm ex- tension, OS w/ 2 3/4" grapple, top sub) to TOF ~ 7740'. Latched onto fish & pulled off fish w/ 25M# over- pull. Could not re-engauge fish. POOH - rec a 2.7" OD SC coupling. RIH w/ BHA #26 (cut-lip guide, btm extension, OS w/ 2 3/8" grapple, top sub). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 13 5/~4/83 11750' TD 7740' ETD (TOF) 13 318" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: ACC COST: $ 28,579 $ 417,820 AFE AMT: $ 940,000 RIH w/ BHA #26 (OS w/ 2 3/8" grap- ple) & latched onto fish @ 7740'. RU Myers & RIH w/ 1 13/16" broach to tag ® 7809'. POOH. RD Myers & RU Go WL. RIH w/ 1 11/16" chemical cutter - stopped 8 7799' WLM. POOH. RD Go WL & RU Myers. Reran 1 13/16" broach - stopped ~ 7809' & was stuck. Oarred loose & POOH (possible crimp in tbg 8 7809'). Circ dwn DP to clean any possible junk. RIH w/ 1 1/2" sinker bars (22' long) - stopped @ 7818'. POOH - had some drag off btm. Reran 1 13/16" broach while pulling on fish w/ 6OM# overpull - broach stopped ~ 7809'. POOH. RD Meyers. Ru Go WL & ran 1" tools (+22' long) - stopped ¢ 7848'. Logged GLM 8 7804' w/ CCL. POOH. RIH w/ 1 3/8" APRS jet cutter on Go WL to 7840'. Pulled up to 7827' & shot cutter w/ 210,000# pull on drill pipe (45M# overpull). Pipe parted in 5 mins. POOH w/ WL. Strapped out of hole w/ DP. 14 5/25/83 11750' TD 7833' ETD (Top of SS) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: ACC COST: $ 30,550 $ 448,370 AFE AMT: $ 940,000 POOH - rec 92.76' including GLM) of 2 3/8" fish (determined to be SS). Top of SS at 7833'. RIH w/ BHA #27 (cut-lip guide, bottom extension, OS bowl w/ 2 3/8" grapple, top sub). Dressed top of LS at 7810' and latched onto fish. Pulled up to 206M#. RU Myers WL through gooseneck. RIH w/ I 13/16" broach. Passed through restriction at 7837' & worked down to 7948'. POOH - found some lead on broach. RD Meyers. Circ through fish. RU Go WL & RIH w/ i 1/2" tools (sinker bar, jars, CCL). Tools stopped at 7948' - could not get deeper. POOH w/ WL. RIH w/ l" tools (sinker ar & CCL) - stopped at 7952'. Worked & pushed down to 7984'. POOH. RIH w/ i 3/8" spent jet cutter on sinker bars - hit 5" x 3 1/2" x O. POOH - cutter ok. RIH w/ I 3/8" 'spent cutter - stopped at 7945'- could get no deeper. POOH w/ WL. Pulled up to 260M# on DR - pkr would not jar loose. RIH w/ i 3/8" jet cutter - worked down to 2nd GLM at 8396' Pulled up to 8377' & fired cu~ter. POOH w/ WL. Worked pipe up to 250M# & parted tbg. POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 5/26/83 11750' TD 10548' ETD (EST TOP OF L.S. FISH) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: ACC COST: $ 31,219 $ 479,589 AFE AMT: $ 940,000 POOH w/FTR #27. Recovered 569.44' of L.S. 2-3/8" tubing fish. (Top of L.S. $ 8379') Ran 5-3/4" O.S. w/ 2-3/8" Grapple (FTR #28). Engaged top of S.S. Fish 8 7833'. Circ. capacity of tubing & D.R. - OK - 400 psi. No fluid loss to FM. RU Meyers W.L. unit & ran 1-13/16" Broach - unable to get below 8013' POOH - RD W.L. Oarred fish ~45M. R.U. A.R.R.S. 1-3/8" tubing cutter on GO Int W.L. unit & TIH. Tubing cutter stopped on GLM $ 10072 WLM. Logged collars & GLM in S.S. Positioned cutter $ 8534 (+. 20' above GLM $ 8554) Cut tu--bing & POOH w/FTR #28. Recovered 701.53' of fish (Top of S.S. fish 8534') Ran 5-3/4" O.S. w/2-3/8" Grapple (FTR #29). Engaged top of L.S. fish ~ 8379. Jarred Baker Model A-5 dual 2-3/8" packer 10521 free w/255M. (NOTE: Had cut L.S. tubing $ 10548 below packer previously.) 16 5/27/83 11750' TD 10547' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW DAILY COST: ACC COST: $ 75,989 $ 555,578 AFE AMT: $ 9AO,O00 POOH w/ dual tbg fish. Recovered 2043.62' of 2 3/8" SS including 63 jts, 5 pups, 5 GLM's, i cutoff, I xa & i "N" nipple, 2163.48' of 2 3/8" LS including 67 jts, 2 cutoffs, 3 pups, 7 GLM's & i "xa", & a 7" dual A-5 pkr. (Note: Rkr was missing btm slips). TOF estimated 8 10548'. RIH w/ BHA #30 (cut-lip guide, 2 hollow mill extensions, OS bowl w/ 2 3/8" grapple, & top sub). Initially took wt ~ 7505' (possible pce of lead). RIH & rotated ® TOF ~ 10547'. Had high torquoe out could not latch onto fish. POOH - rec large ball of .203" WL (f/ SS gun) & 18" pce of 7/8" bar (f/ centralizer on LS jet cutter fish). RIH w/ BHA #31 (6"x5 174"x4 3/4" dressed shoe, 5 3/4" x 5" jt of washpipe, 2 3/8" hollow mill control, OS w/ 2 3/8" grapple, top sub). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 17 5/28/83 DAILY COST: ACC COST: AFE AMT: 18 5/29/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10547' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 26,824 $ 582,402 $ 940,000 11750' TD 10581' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 26,194 $ 608,596 $ 940,000 RIH w/ BHA #31. Worked over TOF ~ 10547' & rotated shoe to 10593' Had high torque. Latched onto ~ish but pulled off w/ 8OM# overpull. POOH - no rec. RIH w/ WL spear & 6" stop on DP to 10556'. Rotated spear & POOH - no rec (Note: 3 barbs on spear bent). RIH w/ BHA #33 (6" ro- tary shoe tapered to 3" ID, welded hollow mill control to 2 3/8", con- ventional hollow mill control to 2 3/8", OS bowl w/ 2 3/8" grapple) & latched onto fish ~ 10547'. Jarred on fish w/ 284M# (8OM# over normal pickup) - would not pull loose. RIH w/ 1 1/2" tools (broach, jars, sinker bars) - could not get into TOF ~ 10547'. POOH - left btm 2" of broach in hole. RIH w/ 1 3/8" jet cutter - could not get into TOF. POOH. Performed blind backoff while pulling 212M#. RIH w/ CCL to confirm backoff below grapple. POOH w/ WL. Completed POOH. Rec 29.03' of tbg including 1 cut-off & 2 pups. Found 2" broach tip in TOF. TOF now ~ 10572'. RIH w/ BHA #34 (5 3/4" guide, 5 3/4" x 2 3/4" short catch OS w/ grapple, top sub). Rotated over & latched onto fish ~ 10572'. RU APRS & ran 1 3/8" free pt indi- cator. Lost grapple hold once while freepointing. Found tbg 100% free ~ 10664' & 100% stuck ~ 10684' Ran CCL & found "XA" ~ 10572', ~ 7/8" blast jts f/ 10602' to 10724', & "XA" ~ 10816'. POOH. RIH w/ 1 13/16" jet cutter - stopped ~ 10844'. Cut 2 3/8" tbg ® 10842' (above prod pkr ~ 10855'). Trip for 1 13/16" jet cutter & cut tbg ~ 10742' (15' below blast jts). Trip for 1 13/16" jet cutter & cut tbg ~ 10577' (below top "XA" sleeve). POOH w/ WL & rigged dwn APRS. POOH w/ DP - rec 9.2' of fish including 1 cut-off & 1 "XA" sleeve. TOF ~ 10581'. RIH w/ BHA #35 (5 3/4" 'cut-lip guide, 2 hollow mill extensions, 0S bowl w/ 2 3/8" grapple, 1 top extension). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ~ELL NO. FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 19 5130/83 DALLY COST: ACC COST: AFE AMT: 11750' TD 10597' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 28,249 $ 636,845 $ 940,000 RIH w/ BHA #35 & latched onto fish ~ 10581'. Attempted to circ-could not. Jarred on ifsh & tbg parted while jarring ~ 31OM# (105M# over-pull). ROOH & rec 15.30' of tbg. TOF ~ 10597'. RIH w/ BHA #36 (cutlip guide, OS bowl w/ 3 21/32" grapple, 5 top extensions). Rotated over TOF $ 10597'. Had high torque while rotating dwn. Had a hold of fish twice but pulled off w/ 80~; overpull. ROOH-found guide chewed up & grapple untouched. RIH w/ BHA #37 (5 3/4" rotary shoe, OS bowl w/ 3 21/32" grapple, 5 top extensions). Began to have torque $ 10587'. Rotated & worked rotary shoe to 10605'. Could not get deeper. ROOH - left btm 4.91' of BHA #37 on hole (rotary shoe, OS bowl, 1 top extension). There were marks on OD of top extensions 13' above twist off. RIH w/ BHA #38 (6" lead impression block, jars, 9 DC's). 20 5/31/83 DALLY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW 30,548 667,393 $ 940,000 Finished RIH w/ 6" Impression Block. Tagged TOF ® 10593' & set 1BM# on fish. ROOH - IB showed 2 3/8" (necked down to 2 1/8") tbg stub up. RIH w/ BHA #39 (5 3/4" cut-lip guide, 5 3/4" OS bowl w/ 2 5/16" grapple, top sub) & latched onto fish ~ 10593'. Rulled 53M# opver normal pickup & made blink backoff. ROOH & rec 13.46' of 2 3/8" tbg cut-off. Top or orig fish (2 3/8" x 2 7/8" XO) $ 10606'. RIH w/ BHA #40 (2 3/4" x 5 3/4" taper tap, xo, B/S, oil jars, xo, 9 DC's) & rotated into lost fishing tools ~ 10603' ROOH & rec all lost fishing tools '(rotary shoe, OS bowl, and top extension). RIH w/ BHA #41 (6" IB). UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. lO LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 21 611183 DAILY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 42,331 $ 709,724 $ 940,000 RIH w/ 8HA #41 (6" Impression Block) & tagged TOF ~ 10606'. Sat down on fish w/ 1SM# & POOH. Rec i6 1/4" of of i 13/16" jet cutter & assembly imbedded in IB. Also had an impres- sion of a I 7/16" rope socket look- ing up that was located i 1/8" in f/ outside edge. RIH w/ BHA #42 (4 1/8" short catch OS bowl w/ 1 3/8" grapple, 4 1/8" top sub w/ decentralizing lug welded on side such that OD across lug is 5 13/16", xo, 2 7/8" pup-lO' long, xo, 3 1/2" pup-19' long). Tagged TOF 8 10606' but could not get over WL fish. POOH-no rec. Lip of OS appeared to have been running on 2 3/8" coupling on top of tbg fish. Worked & built on special rotary shoe. 22 6/2/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' KCL-FIW $ 26,269 $ 735,993 $ 940,000 RIH w/ BHA #43 (5 3/4" x 4 3/4" rotary shoe). Tools set down lOM# ~ 10600'. Pulled 5OM# over string wt to pick back up to 10585'; then came free. Picked up to 10573'. Rotated dwn limiting max torque to 350 amps. Rotated dwn to 10591' & had high torque. Picked back up to 10573' & rotated dwn again. Reamed dwn to 10608'. Reamed very slow thru interval f/ 10599' to 10601' & could not work dwn past 10608'. POOH. Recovered a ball of junk WL inside rotary shoe, small amt of lead f/ IB & small pcs of packer junk. Make up BHA #44. 23 6/3/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 31 SEC KCL Brine $ 36,369 $ 772,362 $ 940,000 RIH w/ BHA #44 (5 3/4" x 4 3/4" rotary shoe & a jt wash pipe). Ran in to 10608' without seeing any obstructions. Washed over fish f/ 10608' to 10612'. POOH. RIH w/ BHA #45 (5 3/4" OS bowl & 3 21/36" grapple). Engauged fish ~ 10606'. Worked & jarred fish pulling +200 M over string wt. Ran ARRS sink--er bars in pipe tools set down ~ 10724' (x-over ~ btm of blast jts). POOH. RIH w/ string shot & free pt. Determined fish to be stuck ~ grapple. Attempted to release grapple - could not release hold. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 11 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field OATE ETD DETAILS OF. OPERATIONS, DESCRIPTIONS & RESULTS 24 614183 DAILY COST: ACC COST: AFE AMT: 25 6/5/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 11606' ETD (TOF) 13 3/8" C. 3130' 9 5/8" C. 9820' 7" L. 7396-11747' 65 PCF 31 SEC KCL Brine $ 27,479 $ 799,841 $ 940,000 11750' TD 10606' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 31 SEC $ 33,904 $ 833,745 $ 940,000 Shot APRS string shot ~ grapple & fired same. Grapple came free-POOH. RIH w/ BHA #46 (5 3/4" x 4 3/4" ro- tary shoe on 1 jt of washpipe). Took wt ~ 10601'. Washed over fish f/ 10601' to 10602' & came free. RI to 10613'. Washed over fish f/ 10613' to 10616'. Trip for new shoe & BHA #47. Went right back to 10616'. Washed over fish f/ 10616' to 10619'. (Note: Pump high vis sweeps as needed for cleaning). Washed over fish f/ 10619' to 10620'. Trip for new shoe & BHA #48. Washed over fish f/ 10620' to 10626'. Trip for new shoe & BHA #49. Washed over fish f/ 10626' to 10629'. (Note: Pumped high vis sweeps as needed. 26 6/6/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10606' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 66 PCF 33 SEC $ 36,410 $ 870,155 $ 940,000 POOH - shoe #5 was bald. RIH w/ shoe #6 on BHa #51 (WO shoe, 1 jt 5 3/4" washpipe, washover boot basket, xo, 2 boot baskets, bit sub, B/S, oil jars). Jad relatively high torque on btm - 500 amps. Washed over f/ 10629' to 10631'. Pulled up to 9 5/8" csg to shake off possible junk. RIH - had 500 amps w/ shoe @ 10605' ~ 44 RPM. POOH to check shoe. Shoe appeared ok. Changed out washpipe due to external cutting. RIH w/ shoe #7 on BHa #52 (same as #51). Rubbered DP on trip in. Reamed down f/ 10629' to 10631'. Washed over f/ 10631' to 10635'. Ran 120 bbl viscous gel sweeps periodically to clean btm of hole. Torque appeared to be decreasing. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 12 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 27 5/7/83 DAILY COST: ACC COST: AFE AMT: 28 6/8/83 DAILY COST: ACC COST: AFE AMT: 29 6/9/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10630' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 67 PCF 34 SEC $ 35,112 $ 905,267 $ 940,000 11750' TD 10630' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 67 PCF 42 SEC $ 31,323 $ 936,590 $ 940,000 11750' TD 10630' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 67 PCF 42 SEC $ 30,456 $ 967,046 $ 940,000 Washed over & milled f/ 10635' to 10639'. POOH. RIH w/ BHA #52 (cut- lip guide, 0S bowl w/ 3 21/32" grap- ple, 2 top extensions, top sub, etc) & engaged fish ~ 10610', guide @ 10618'. Pulled 360M# (90M# over normal pickup) & pulled loose. Ran down & guide went to 10622' (4' low- er than previously). Pulled loose w/ 40M# overpull. RIH to 10622' & attempted blind backoff - had indication of backoff in DP. POOH - found 5" DP loose 2 stds down. Tightened 5" DP. POOH - rec XO and 1 blast jt (2o.55' OA). Blast jt appeared to part in threads. The btm 4' of blast jt had been milled flat on one side (to 3 1/4" OD) & apparently had been beside itself down hole. RIH w/ BHA #53 (6" x 4 3/4" rotary shoe, 1 jt of washpipe, washover boot basket, XO, 2 boot baskets). Worked over TOF ~ 10630' & WO f/ 10638' to 10641'. Pulled up & dragged junk up the hole. Remilled f/ 10638' to 10640'. POOH. Finished POOH. (Rotary was com- pletely bald). RIH w/ rotary shoe #9 on BHA #54 (same as #53). Reamed f/ 10635' to 10640' & milled f/ 10640' to 10642'. POOH. Shoe #9 was completely bald. RIH w/ rotary shoe #lC (6" x 4 3/4" 3 3/4" throat) on BHA #55 (same as #54). Washed over & milled f/ 10641' to 10645'. POOH - shoe was bald on btm & 70% worn in throat. There was a 1/4" groove on btm. RIH w/ rotary shoe #11 on BHA #56 (same as #55). Milled w/shoe #11 on BHA #56 F/10645' to 10652'. Trip for new shoe. With shoe #12 on BHA #57 milled F/10652' to 10658' and fell free RIH to 10663' (Bottomed out on wash pipe). Circ clean & POOH. RIH w/BHA #58 (o.s. w/3-21/32" grapple etc.). Engaged .fish ® 10630' without seeing pack off, picked up 10T-No. indica- tion & fish. RU APRS WL & RIH w/same 1-3/8" CCL & sinker bars. couldn't go thru grapple - indicating that have fish. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 13 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 30 6/10/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10676' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 67 PCF 42 SEC $ 36,924 $1,003,970 $ 940,000 Pulled WL. POOH w/ DP. Recovered 1 blast jt 20.07' long & 20" pce 1 1/2" on top. RIH & engauged fish w/ fishing assy #59. Unable to jar fish loose. Blink backoff & POOH. Rec 1 full blast jt 20.00' long. RIH w/ fishing assy #60, retary shoe on wash pipe. Washed over fish ~ 10676' & cleaned down to 10744'. Circ clean. POOH. 31 6/11/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 10864' ETD (TOF) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 66 PCF 46 SEC $ 103,257 $1,107,227 $ 940,000 RIH w/ fishing assy #61. Engauged fish $ 10676' - POOH. Rec 74.60' of fish. RIH w/ fishing assy #62. En- guaged fish $ 10750'. POOH. Rec 101.00' of fish. RIH w/ fishing assy #63 & engauged fish ~ 10851'. Pulled seal assy out of pkr. Circ clean. POOH. Rec entire seal assy to mule shoe. RIH w/ fishing assy #64 (pkr picker). 32 6/12/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 11516' ETD (JUNK) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 44 SEC $ 27,127 $1,134,354 $ 940,000 RIH. Burn over perm pkr ~ 10864' in 1 hr & 50 min. POOH. Rec pkr. RIH w/ fishing assy #65 (concave junk mill). Tagged junk & fill e 11504'. Cleaned out f/ 11504-11514' & mill plugged. POOH. Test BORE to 3000 psi. RIH w/ fishing assy #66 (6 blade junk mill). Milled f/ 11514' to 11516'. 33 6/13/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 11516' ETD (JUNK) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 40 SEC $ 29,555 $1,163,909 $ 940,000 Circ well clean @ 11516'. POOH. LD BHA #66 (junk mill #2). Cutting surf 100% gone. PU BHA #67 (globe basket w/ shoe mill & boot basket). Tagged junk ~ llS16'-unable to rotate fishing tools below 11516'. POOH. Shoe on globe basket 100% worn out. No recovery. LD fishing tools. RU GO Int WL unit & ran Dialog 7" csg inspection log f/ 11450' to top 7" liner $ 7396'. POOH. RD WL Unit. Replace hi clutch on drawworks drum. RU 6" concave mill & 7" csg scraper. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 34 6/14/83 CAILY COST: ACC COST: AFE AMT: 35 6/15/83 11750' TD 11516' ETD (OUNK) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 65 PCF 39 SEC $ 20,879 $1,184,788 $ 940,000 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine DAILY COST: $ 39,639 ACC COST: $1,223,822 AFE AMT: $ 940,000 36 6/16/83 DAILY COST: ACC COST: AFE AMT: 37 6/17/83 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine $ 64,235 $1,288,057 $ 940,000 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine DAILY COST: $ 18,755 ACC COST: $1,306,812 AFE AMT: $ 940,000 38 6/18/83 BALLY COST: ACC COST: 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' 6% KCL Brine $ 18,865 $1,325,677 Ran 6" concave mill on 7" csg scrpr to 11516'. Had indication of re- striction in 7" from 10590' to 10600'. POOH. Ran 8 1/2" bit in 9 5/8" csg scrpr to TOL ~ 7396'. POOH. Repaired elec line in draw- works "B" motor. Reran 6" mill & 7" csg scrpr to 11516' - did not see anything 8 10590 to 10600'. POOH. RIH & set RTTS ~ 10500'. Press tstd 7" & 9 5/8" above 10500' to 1500 psi for 15 min w/ no leakoffi. POOH. RIW w/ OEDP, fill DP w/ FIW & sand out to 11490'. X-over to new 6% kcl brine. Spot 50 bbl perf pill of 6% kcl w/ 2 1/2PPB "xc" & 21PPB CaC03 f/ 11490' to 10142'. POOH. Rigged up DA. Perfed HB #4 w/ 4 HPF using 4" csg guns f/ 11372' to 11402' & 11352' to 11372'. Perfed 4 HPF w/ GO Int 4" csg guns the following intvls:HB #4 f/ 11332' to 11352' & f/ 11294' to 11324'; HB #2 f/ lll02' to 11132'; HB #1 f/ 11058' to 11078'; G-3 sand f/ 10668' to 10708' & G-2 sand f/ 10620' to 10645'. Ran WL GR to lllO0'. Set Baker "F" pkr ~ 10856' on WL. RIH w/ 2' of seals & test pkr ~ 10856' DIL. Tagged pkr ~ 10877' DRM & tstd same to 650 psi. POOH laying down DP. Changed pipe rams dual 2 3/8" lower & 3 1/2" x 2 7/8" in middle. RU to run dual completion assembly. Ran dual comp assy w/ 2 3/8"x2 3/8" dual in 7" liner & 3 1/2"x2 7/8" dual in 9 5/8" csg. Had 105M# down wt & 155M# up wt prior to lndg tbg. Tstd LS seals in perm pkr e 10856'. RU Meyers WL & set "XN" plug in LS e 10921'. AFE AMT: $ 940,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 15 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 39 6119/83 DAILY COST: ACC COST: AFE AMT: 40 6/20/83 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-i1747' 6% KCL Brine $ 316,244 $1,641,921 $ 940,000 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' DAILY COST: $ 18,755 ACC COST: $1~660,676 AFE AMT: $ 940,000 41 6/21/83 DAILY COST: ACC COST: AFE AMT: 42 6/24/83 DAILY COST: ACC COST: AFE AMT: 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' $ 17,237 $1,677,913 $ 940,000 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' $ 19,657 $1,697,570 $ 940,000 Set & tested Baker "A-5L" dual pkr 10488' w/ 1000 psi down annulus. (NOTE: Ran SS w/ dummy GLV's in mandrels). Rulled "XN" plug nipple $ 10921'. Slacked off 2' & landed tbg in tbg spool. Opened btm XA in LS $ 10834'. Installed BRV's, re- moved BORE, installed & tested dual CIW tree. Move rig to leg room #3 while unloading G-8 RD. Released rig to AFE # 331402 G-3 RD $ 24:00 hrs, 6/21/83 for naphtha & FFA-I treatment. RU over G-8 RD WO for acid job on "G" zone perfs. Offloaded acid onto Grayling Rlatform. RU Dowell & di- luted acid toproper concentrations. Bled gas lift press off of ann. RU Myers WL on LS & RIH w/ "XN" plug- could not get below 10845'. ROOH. RIH w/ shifting tool & closed "XA" sleeve @ 10834'. ROOH. RIH w/ "XN" plug & set plug in "XN" nipple ~ 10922'. ROOH. RIH w/ shifting tool & opened "XA" sleeve in LS ~ 10834'. ROOH & RD Myers WL. Tstd surf lines to 5000 psi. Displ 57 bbls of 7 1/2% HCL w/ .5% A-200, · ,4% F-75N,.2% J-237, .2% W35, .4% L53W, and 65 lbs L-41/lO00 gal down SS while taking fluid returns up LS. Discovered that HCL was contaminated w/ a greasy substance. RU myers WL & closed "XA" sleeve in LS ~ 10834', Sent sample of HCL to lab to be analyzed, Filled annulus in TBUS G-27 while waiting on analysis of acid, UNION OIL COMRANY~OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 16 LEASE ADL #18730 WELL NO. G-8 RD WO FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 43 6/25/83 11750' TD 11490' ETD (Sand) 13 3/8" C. 3031' 9 5/8" C. 7820' 7" L. 7396-11747' DAILY COST: ACC COST: $ 28,325 $1,725,895 AFE AMT: $ 940,000 RIH in LS & opened "XA" sleeve ~ 10834'. Pumped down LS & out SS to remove contaminated acid f/ tbg. - Sent new 7 1/2% HCL mix out to Grayling. Displ SS w/ 52 bbls of 7 1/2% HCL w/ .6% A-200, .4% L53W, and 65 lbs L-41/lO00 gal. Closed "XA" sleeve in LS ~ 10834'. POOH sleeve ® 10834'. POOH w/ WL. Pumped additional 20 bbls 7 1/2% HCL mix followed by 100 bbls of 6 1/2% mud acid w/ additives. Observed pressure on LS & annulus increase to 2200 psi while pumping in SS w/ 2 1/2BRM ~ 2500-3000 psi. Shut-in SS. Pressure on SS fell to 0 psi while the pressure on LS & annulus remained ~ 2200 psi. Bled annulus pressure to 1000 psi (all gas) & LS pressure dropped to 1400 psi. RIH in LS & confirmed all "XA" sleeves closed. POOH w/ WL. Continued w/ acid job. Pumped 55 more bbls of mud acid followed by 15 bbls of 3% NH4CL spacer ~ I BRM w/ 2500 psi. Pumped 155 bbls of clay acid w/ additives followed by 10 bbls of diesel w/ 10% U-66. Displ acid w/ 31 bbls of diesel. Shut-in well for 8 hrs. Released rig f/ G-8 hRD WO to TBUS 6-27 WO ~ 24:00 hrs. ' ' GRADE ~ *' ' cou.,~ I STATE , ' ~"~ ,, I'! ~ ~, i~ ~READ. I I ,, ~ NEW ~ MAX. MIN. DEPTH O.D, I.D. LENGTH FEET ITEM ~ _ __ DESC~IP%ION - ' -- ~I 2 o ,.;~ .~,,~.. ~ ( ;.... .,-:,~~ .~/.V9 ,~t~;.,~l .~:; ,-.,=~ _._~._.:___z ~ ' ii ~.', - ~ ~'~ ',.' ._,._ , ..<z. r;u~ , -:, :. ,, ('~ J'aJ~:;~b' :;q~. '-? {,'. ~3.,"" *t~',, ~ ¢ ..... - ' ~ I"J '- ' ' ~" F" ~ ~n.'~-'m' d., ~'.',~ rz~'.~'.~~~~~~ ' '~ ' ' PHONE PREPARED 13Y ._'.'., .,,: ) Y [ ...... _,,,.. ,, ,,, .,,,,,,,,,,,,,,,, I*,11. IIIII :llr'lll * tlllllllll'lll~ II:I^11 TELEI'~[IONE (7 $3t 023-0361 · 'fi:LEX 76.2833 A DIVISION OI= DAKE~ OIL TOOLS GROUP. BAKER iNTERNATIONAL CORPORATION f IIIIM i'"t(..i. 70-15 CO,~PA.¥. L~ t0 \ ~'43 (3 t L SIZE wEIGHT GRADE T~READ DEPTH MAX. MIN. O.D. I.D. ,.c._~s ,Nc.eS ~ ' ' j ' _ _ t DEPTH LENGTH I FEET ~.~~ 7Y' ,.:~ ~_~___Z] o '-' -'< ' ?~_l.J ~~ qtl ' O_ Y.£) ,,;~ ._L!,'. :ii__ [P.EPA.EDFORi I ~x.\ \ ~._ p.. . .. . ~, ' (h~l PREPARED JPHONEo~,c~ ? ? L-- R I 2 I k'~" ;,:) fl I , 6023 NAVIGATION BOLILEVARD P O BOX 3048 * HOLJ.c TON. T~XAS 77001 TELEPHONE (7131 923-.q351 ' TELEX 76-2833 A DIVISION OF BAKER OIL 'I'OOLS GROUr' !fAKER INTERN~,TIONAL CORPO~A'trlo~ -- _. I-n~lM N(.). I0 i' . .M. ...... .;..: . -- ,' , , , j, . : .: ....... ,. ......... Y WEIGHT FIELD % .-, · , , . (~ ~ )t .... .. ~ ~.~/~ . GRADE ~,~ -~ [ ~. ~ }~ ..... ,~ r ~ ..... · I STATE t:I i .' ~. ~., ~..~ THREAD ~t ~ ~, ,_~) .,,. ~ ~,/~ ~ ~ w.o. DE,~. .. . ... ., . . I ITEMI . ~ '-- _. _ ~ESCRIPTIO~ _ = MAX. MIN. DEPTH O.D. ~.D. LE.GTH ~EET ! ~O~T . ; STR I ~ ~, INCHES INCHES FEET ~ .,~ ~~~ ........ t';,' 'c',~ ' ~ ~a ~,/u~ ~-,~.~.,~ ~,-,-~ ;..-.. . · ')~ .... w~ · ' ~/ ~' ~"I '~t ~// .~" q/' ~ , ,~ ~.~~;~ ~ y z,.)~ ~,~] ' .~'~.~ 2~,~ ~. ~.' ~:~',, ~,,, ~ ~., Pl.!~,~ . . .72 ~ ,~~L ~1 A · PREPARED FOR (A r~')le::~x~ ~ l.. 0.('3. or' Q f-'Xi,~{.- P[IE~)ARED [~Y ' JPHONE'}?/-- ~i3 / 6023 NAVIGATION BOULEVARD P.O. DOX 3048, HOUSTON. TEXAS 77001 TELEPHONE (713) 923-9351 · TELEX 76-2833 DIVISION OF DAKER OIL TOOLS GROUP. D^t~ER IN1 £RNATIONA[ CORPORATIOt rnnM NO. 70-15 I FIELD TO~ I~ ~ ~ ~ ~/ WEIGHT ~ ~ ! ~ ~ ~~)l~ ....... l' i .i ''.il ,, i I r I ............... I [ m I iAx MIN I " DEPTH I I O E S C R ' "T [ 0 N ~ ' O ~ ; ''DI' [ LE~G{H FEET II . ' , ' . INCHES INCHES: F E ; ..... '~ , ,.' , ,, ' . , . _ , ..... , ,., . . . ~ , , . ' , . , , , , ,, , , ~ i , , ~_ "" , ...... t,., ,, ....... ~ ~ '1 .... ,, , ,, ,,, ~ ............ [ ...... , , , ,, .REP^RED FOR Q f't)i 0 ,,,,,,,,,, ,,,,,,,,,,, ,,,,:,,,,, ,,,,,,,,,,, IELEPHON~ ,713,023-03B1. T~LEX 7~-2,33 DIVISION OF BAKER OIL TOOLS GROUP, BAKER INiERNATIONAL CORPORATION STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator UNTON O]:L CONPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99:502 4. Location of Well Conductor #45, Leg #2, 1874'N & 1382'W of SE corner, Sec. 29, TgN, R13W, SM. 7. Permi[ No. 78-45 8. APl Number 50- 733-20085-01 9. Unit or Lease Name TRADING BAY UNTT 10. Well Number TBUS G-8 RD 11. Field and Pool McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' MSL I ADL 18730 Hemlock Fm. & "G" Zone 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 Proposed 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). See Attached I14.I hereb~rtify that the f~go~s true and correct to the best of my knowledge. (:.: ''~ ~ ,~,-.~t '?//C ];, ~~ ~~~~ ~~¢T,t.. D, str, ct Drlg Super,ntendent Date 7/''/8' Signed/ /-~- , . - The sp~ce~l°Wfor Commission use Condi~//ofApproval]~ Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate TBUS G-8 RD Sundry Notice July 11, 1983 13. Description: le 2. 4. . ,, 7. 8. 9. 10. 11. 12. 13. 14. 15. Rigged up over TBUS G-8 RD on 5/12/83. Well was dead. Recovered fish f/ 572-580' in short string. Opened "XA's" in long string and pumped kill fluid into long string. Installed BPV's, removed tree, installed and tested BORE to 3000 psi. Fished and laid down dual completion assembly. Cleaned out well to 11516' ETD. Ran 7" csg inspection log f/ 11450-7396' (top of 7" liner). Tested 7" and 9 5/8" csg above 10500' to 1500 psi - ok. Rerfed w/ 4 HRF: HB #4 f/ 11332-11402' HB #4 f/ 11294-11324' HB #2 f/ iii02-11132' HB #1 f/ 11058-11078' G-3 f/ 10668-10708' G-2 f/ 10620-10645' Set Baker "F" pkr ~ 10856' and test to 650 psi -ok. Ran dual completion assembly w/ Baker "A-SL" dual pkr ~ 10488'. Tested pkr to 1000 psi down annulus - ok. Installed BRV's, removed BORE, installed and tested dual CIW tree. Stimulated "G" zone w/ 72 bbls of 7 1/2~ HCL, 155 bbls of 6 1/2~o mud acid and 155 bbls of clay acid. Released rig f/ G-8 WO on 6/25/83 to production. ,.~_. ~ STATE OF ALASKA ALASK )IL AND GAS CONSERVATION (, MMISSION MONTHLY FII=POFIT OF DFIILLINO A#D WOFIKOVEFI OPI=FIATIO#$ · Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. UNION 0IL COHPANY OF CALIFORNIA 78-45 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 733-20085-01 9. Unit or Lease Name TRADING BAY UNIT 4. Location of Well at surface Conductor #45, Leg #2, 1874'N & 1382'W of SE corner, Section 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' MSL I ADL 18730 10. Well No. TBUS G-8 RD 11. Field and Pool HcARTHUR RIVER FIELD HEHLOCK FM & "G" ZONE JUNE 83 For the Month of , 19__ '12. Depth at end of month,footage drilled, fishing jobs, directional drilling problems, spud date, remarks Fished f/ 10603-10864' Set packer ~ 10856' & dual ~ 10488' Recovered rest of long strlng Ran dual completion assembly Cleaned out to 11516' Completed 6/25/83 TMD ~ 11490' (Sand) 6/30/83 13. Casing or liner run and quantities of cement, results of pressur9 tests Tested 7" and 9 5/8" csg above 10500' to 1500 psi - ok 14· Coring resume and brief description None 15. Logs run and depth where run 7" Casing Inspection log ¢/ 11450-7396' ,,1 6. DST data, perforating data, shows of H2S, miscellaneous data Periled 4 HPF: HB #4 f/ 11332-11402' " " 11294-11324' HB #2 f/ 11102-11132' HB #1 f/ 11058-11078' G-3 f/ 10668-10708' G-2 f/ 10620-10645' Acidized "G" zone w/ 72 bbls of 7 1/2% HCL, 155 bbls of 6 1/2% mud acid, and 155 bbls of clay acid. 17. I here~ that the foregoing is true and correct to the best of my knowledge. SIGNED ......... E DISTRICT DRLG SUPT DATE 7/11/83 NO/~-.~p~rt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oi(-a~f'd Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ~.~ ~-- STATE OF ALASKA (~g.~j~ ALASK~ ~II..AND GAS CONSERVATION C .~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5% . DrilJingwell Fl WorkoveroperationJ~ j~ Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 78-/*5 ' .~- 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 733-20085-01 9. Unit or Lease Name TRADING BAY UNIT 4. Location of Well at surface Conductor #45, Leg #2, 1874'N & 1382'W of SE corner, Section 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' MSL I6. Lease Desiqnation and Serial No. ADL 18730 NAY For the Month of ,1 10. Well No. TBUS G-8 RD 11. Field and Pool McARTHUR RIVER FTELD HEMLOCK FM & "G" ZONE 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations on 5/12/83 Fished f/ 57~-10603' TOF ~ 1059~' MD 5/31/83 Recovered dual tbg string to dual pkr ~ 10521'. Recovered long string to 10603'. Continue fishing. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run.and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby ify that the foregoing ' ue and correct to the best of my knowledge .... ~h: i .... - ..... -u,:,,:~Ul~ NOT~¢Zt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil ~as Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE OF ALASKA '- ALASKA .',..,.L AND GAS CONSERVATION Cf. .... MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX] OTHER [] 2. Name of Operator 7. Permit No. UNTON 0IL COMPANY OF CALIFORNIA 78-4.5 3. Address 8. APl Number P, 0, Box 6247, Anchorage, Alaska 99,502 50- 133-2008.5-01 4. Location of Well Cond. #45, Leg #2, 1874' N, 1382' W of SE corner of Sec. 29, TgN, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' above MSL 12. I 6 . Lease Designation and Serial No. ADL 18730 9. Unit or Lease Name Trading Bay Unit 10. Well Number G-8 RD 11. Field and Pool McArthur River Field 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 Proposed 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 NOT reperforated October 31, 1980: Sand B-1 B-2 B-4 Perforations 11,058' - 11,078' 11,102' - 11,132' 11,294' - 11,324' 11,332' - 11,402' Approval was received October 9, 1980 however, work will not be completed. 14. I hereby certify that the f~.r.e~g i~ ,tr~e and correct to the best of my knowledge. ~<C~.~t~//~& District Engineer Signed r, ,, ,-,_ Title The space below for Commission use Date March 21, 198] ~ fv--/-~"~ 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 .... . STATE OF ALASKA -' ALASKA ~..~ AND GAS CONSERVATION CC,.,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] March 21,. 19 ~3 2. Name of Operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 78-4:5 3. Address 0 Box 6247, Anchorage, Alaska Location of Well 99502 Cond. #45, Leg #2, 1874' N, 1382' W of SE corner of Sec. 29, TgN, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) ' above MSL 12. I 6 . Lease Designation and Serial No. ADL 18730 8. APl Number 50- 133-20085-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number G-8 RD 11. Field and Pool McArthur River Field 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 pletions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed 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 NOT reperforated October 31, Sand G-3 G-4 Perforations 10,624'- 1~0 6~- 10 6 ' 10,668' fill 7~ · 1980: Approval was received October 9, 1980 however, work will not be completed. 14. I hereby certify that the f%~_.e.~oi/~§ is true and correct to the best of my knowledge. ~(~.-'/~,'...:' [~""' ' ~ District Engineer The space belowL~r C/Tlo~nm~masiSo~n u~e Date 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 Pebruary 16, 19~3 Union Oil Compa~ of .California P.O. Box 6247 Anchorage, Alaska 99502 Re: g~bs~uent Reports, Sunder Notices and Reperts on Wells (Form 10-403 } For the following lists of No. ice of Intention To:" Sund~~ Notices and ~e~rt on ~-$ells (form 10-403) this office does not have oD. record the "Subs~uent !~eport of:" defining the action taken on the approved intention. Please advise this office. ~.~, SubS~uent 9eport of the disposition ol the inte~.tion. %~ell UniOn Date Brief Oesc~i~.tio..n g~. Int~cn~ion TDU G-7 4i21/82 TBUS G-2 5/24/[~2 T~US C-3 ~/30 / ~2 ~- iRD 7/1.4/g2 Re~erfcrate C-3, C-4 ~eE~crfcrate b-l, B-2, ~i-4 }~eperforate B-5, ~-i, L-4 ~eperforate ~.eper forate Perforate B zone Clean out, re~erforatc Plug & ak~andcn for sic~.etrack ~ull tubing, reper~orate Squeeze cement to abandon hen loc3~ Change kickoff ~oint Reperforat e P~evise setting aLandonment retainel ~epa. J.r ca.j in~ Perforate STATE OF ALASKA -' ALASKA OIL AND GAS CONSERVATION CO,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator UNION 0TL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99.502 4. Location of Well sCon,dvctor_~ ec~on 2y ~45. Lea #2, 1874'N & 1382'W of SE corner, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' MSL 6. Lease Designation and Serial No. ADL 18730 7. Permit No. 78-4.5 8. APl Number 5°733-20085-01 , 9. Unit or Lease Name TRADING BAY UNIT 10. Well Number TBUS G-8 RD 11. Field and Pool McARTHUR RIVER FIELD HEMLOCK FM & "G"-ZONE 12. (Submit in Triplicate) Perforate [] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed 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). To puli tubing, recover wireline fish, reperforate the stimulate the "G",zone and return to production TBUS G-8 RD, Cook Inlet, Alaska. Procedure: Hemlock and "G"-zone, McArthur River Fleld, 1. Move rig equipment from leg room #4 Rig #55 to leg #2 Rig #54. 2. Move Rig #54 over TBUS G-8 RD and rig up. 3. Kill well. Install BPV's, remove tree, install and test BOPE~ro 4. Pull dual tubing completion assembly. .5. Clean out to +11623' ETD with 2 3/8" sti~er on 3 1/2" DP. 6. Perforate Hemlock and "G"-zone. 7 7. ~ "G"-zone perfs and acid stimulate "G"-zone. 8. Run dual completion assembly. 9. Return well to production. DEC , i982 Alaska Oil & Gas Cons. Con]mission Anchorage 14. I hereb¥.~ertify that the foregoing i~,oJ;rect to the best of my knowledge. Signe~'~.~_:~:¢~ /]~.,-5~..~'~:/'~]~/ ,? ~ T,i~tle District Drlg Superintendent The ~¢ace be ow fCr Comm ssion use//. .. ,.' x2-~;/~/r~.x.x~ _ ,~:. · Conditions,. of Approval, If any: ,' ' : ~ A:,F¢oved Copy " E~4urned Approved b~. .,: COMMISSIONER the Commission Date 12/14/82 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ;Form 10.403 REV. 1-10-73 Sublnlt "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 /or proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR P.O. Box 6247, ANchorage, AK 99502 4. LOCATION OF WELL At surface 5. APl NUMERICAL CODE 50-133-20085-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18730 7, IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9, WELL NO, TBUS G-8RD 10, FIELD AND POOL, OR WILDCAT McArthur River Field Cond. #45, Leg #2, 1874' N and 1382' W from SE corner, Sec. 29, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Rt gg' ahnv~ 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. 78-45 )crt, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other),Reperf0rate existinq intervals SUBSEQUENT REPORT OF: WATER SHUT-OFF E~ 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 all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We propose to reperforate the following intervals in the G zone. G-3 10,624 - 44/ G-4 10,668 - 708/ 16. I hereby certify, that the foregoing Is true and correct ~~ ~/' .~-~L~ District Enqineer $,GNED C. H. CASE T,TLE DAT£- (Thlsspacef°rState°f,~luse~) :j~ ~ ~ . C~Z~L~--~2;'~~~ ~,' ~T~. ~$'T-~ APPROVED BY ~~ ~~ TITLE.' I DATE CONDITIONS OFA~VAL, IF~NV= BY ORDER OF ~E CO~JM)Sg)ON l 0/1/8O See Instructions On Reverse Side Form D-IOOI-A UNION OIL CO. OF CALIFORNIA REPAIR RECORD LEASE Trading Bay Unit State WELL NO G-8RD CONTRACTOR Parker fIELD McArthur River TYPE UNIT 1320 National :EGAN: 11/18/79 COMPLETED~ 12/20/79 ELEVATIONS: GROUND fERMIT NO. 78-45 SERIAL NO. ADL-18730 CASING HEAD. TUBING HEAD_ -OMPA2,~Y E~GI:'TEER, Dibbley -zM%Allist~ ,,~-j~Gr.~ham __ ' ...... SIZE DE. TH WEI C, HT G~ADE REMARKS SHEET A PAGE NO. (-'~'~) ¸':7 ROTARY DRIVE BUSHING 99' to MLLW 20" 16" i3 3/8 9 5/8" For 358' 589' 3103' 7802 ' ] 17"7'. :'ub lng Si ~" Wall Drive 75¥/ J-55 61¥/ J-55 43~ & 47# N-80 z9# ~N-80 ~_e Tubing D,~,tail Pipe Cmt'd w/1200 sxs. w/additives. Cmt'd w/2300 sxs. w/additives. Cmt'd w/3300 sxs. w/additives. Cmt'd w/830 sxs. w/additives. Top @ 7396'. PERFORATING RECORD ~T----~--q INTERVAL 8/3/781112'64 to 11266 8/8/78110668 to-10708 8/9/78 ~!0620 to 10645 8/ 21zS 113 o~ to 11401 8/12/7~ 11294 to i132g 8/13/7g 10668 to 1070~ ~i/30/7~ 11430 to 11432 ~2/2/29~ 11264 to 11266 ~2/8/19! 11332 to 11402 11324 to 1129~ 10668 to 10708 10620 to 10645 '2/9/79 ,2/9/79 0/9/79 ~.T.D. 11623' 11230' 11230' 11623' 11623' 11623' 11623' 11285 11623' 11623' 11623 11623' REASON To. Sqz. Production !! !! ,! To Sqzo To Sqz. Production ,, !! PRESENT CONDITIO~ Sqz'd w/100 sxs. G-4 Sand - Open. G-3 Sand - Open. H.B. #4 Sand - Open. iH.B. #4 Sand - Open. G-4 Sand - Open. Sqz. w/150 sxs. Sqz'd w/250 sxs. H.B. #4 - Open. H.B. #4 - Open. G~4 - Open G-3 - Open. )DUCTION AFTER REPAIR DATE I INTERVAL NET OIL CUT ! GRAV. J C,P, T.P. CHOKE I MCF GOR REMARKS I I --, , WELL HISTORY PRIOR TO REPAIR 12/20/79 ZOMPLETION DATE: ?RODUCiNG :NTERVAL: 3NITIAL PRODUCTION: LAST COMPLETION NO.. LAST REGULAR PROD. & DATE: ZUMULATIVE PRODUCTION' ZEASON FOR REPAIR: Isolate water entry in N~ml~ck zone, S ,EET PAGE LEASE Trading Bay Unit U IIO I OIL CC .'PA ff OF CALIFOPC,IIA . ELL I ECO G-8RD I' LL HO, FIELD McArthur River DATE DETAILS OF OPEP3'~TION$, DESCRIPTIOiIS g RESULTS . !0 !1 11/18 79 1!750' TD 11623' ET 9 5/8" c. [7820' 7" L. 739~' to 11747' 11/19/79 11750' TD[ 11623' ETE (cmt) 9 5/8" C. 7820' 7"L. 7396 to 11747' 11/20179 11750' TD 11623' ET] 11/21479 Commence operation 00:01 hrs. 11/18/79. Moving rig f/Leg (cmt) Room #3 to Leg Room #2. 11/22 11/23 /79 79 Moving rig f/Leg Room #3 to Leg Room #2. Moving rig f/Leg Room #3 to Leg Room #2. (cmt) 9 5/8" C.~7820' 7" L. 7391' to 11747 11750' TD~ Moving rig from Leg Room #3 to Leg Room //2. 11623' ET~. (cmt) 9 5/8"-C. t7820~ · . 7" L. 7396[' to 11747' . · ~ . · . 11750' TD~ Moving rig from Leg Room #3 to Leg Room #2. 11623' ET~ (cmt) ' 9 5/8" c. i7820' 7" L'. 7396t' to 11747' . 11750' TD I Completed move f/leg room ¥/3 to leg room #2,, 11/23/79. , 11623' ETD[(cmt) Opened "XA" in L.S. @ 10827'. Pumped 120 'bbl. pill of 6% 9 5/8" C. ~820' KCL w/2 PPB "XC" & 20 PPB Safe-Seal down L.S. Spot 80 bbis. 7" L. 73961' to 11747'/ across "G" zone peris & 40 bbls. to Hemlock perf's. Fiti~ annulus w/FIW. Pulled & layed down S.S. 11/24/179 11750' TD Attempt to pull pkr. loose w/L.S. - No luck. Jet cut L.S. 11623' ETD (cmt) @ 7127'. Layed down L.S. 5/8" C. 7820' ~" L. 7396 to 11747' 11/25/~9 11750' TD Engauged L.S. @ 7127' w/O.S. Pulled O.S. off fish. Trip & 11623' ETD (cmt) redressed O.S. Engauged fish @ 7127', Pooh w/L.S. (recovere 9 5/8" C. '820' 1.6' of junk f/top of triple'pkr~) ' 7" L. 73961' to 11747' I 11/26/ 9 11750' TD I " Completed laying down L.S. w/dip tube. RIH w/8t-~'' bit to 11623' ETD~(cmt) ' top of liner @ 7396'. Circ. well clean w/FIW. Pooh. , 1 9 5/8" C. ~820 ' (NOTE: 8~ bit ran in & out with no indication of damaged 7" L. 7396 -11747' pipe). Ran 8~" gauge ring -' stopped @ 5227'. Ran 8 3/8" gauge ring to 7396'. Ran collar log f/7396' to 4500'. Collar log indicates damaged csg. @ 5227'. 11/27/~9 11750' TD Wait on Dia-Log unit to run csg. inspection log bad weather 1t623' ETD (cmt) " 9 5/8" C. 820' 7" L. 7396 to 11747' · ll/28/79 I1750' TD Ran Dia-Log 9 5/8" casing inspection log f/7396' to surface. 11623' ETD (cmt) Casing pitted f/+_7396' to +__6900'. RIH w/Baker retriev-a-mati 9 5/8" C. ~820' Set sqz. tool @ 7820' &'tested 9 5/8" csg. above sqz. tool tc 7" L. 7396 -11747' 2000 Psi. Pooh. RIH w/Packer-Picker to 7" Otis perm. pkr. · E C V E D D E C ! 1 l!:~ C.O Alaska Oil & Gas Cons. Commission Anchorago S~EE7 D PAGE I~O, uiiiorl OIL C~,~?NN OF CALIFO~.IIA 1,,ELL IfCORD LEASE Trading Bay Unit I',~LL HO, ~-8Rg FIELD McArthur River DATE 12 13 ETD 11/29/19 i1750' TD j 11623' ETD .7396'0~ ii/30/..9 11750' TD 11623' ETD 9 5!8" C. $ 7" L. 7396' DETAILS OF OPEP~TION$, DESCRIPTIOrI$ g RESULTS (cmt) '820' ,1747' Changed over to W.O, fluid. Tagged pkr. @ 10850'. Pkr. moved down hole to 10866''(Pkr. Not Set). Attempt to engaug£ pkr. Pooh. No rec. redressed grapple. RIH - couldn't work spear into pkr. Pooh. Left spear in hole. Burned over Otis Pkro @ 10866'. Pooh. Rec. Pkr. & Spear. Ran 6" bit & 7" csg. scrpr. Tagged fill 11587'. Circ, clean 820' & Pooh, Perf'd below H.B. #4 for isolation szq. f/11430' to -11747' 11432' w/4 - 1~" HPF. Ran gauge ring and junk basket to 11420', Alaska Oil & Gas Cons. CommissJor~ Anchora§o SHEET D PAGE !'b, UiiIOtl OIL CQ'!PAIN CALIFO tIA I;, LL t ECORD LEASE I' I LL HO, FIELD DATE 14 15 16 17 18 19 12/117c. 12/2/7I I 12/3/79 12/4/79 11750' TD 11285' ETD 9 5/8" C. 7 7" L. 7396' DETAILS OF OPEP~TIONS, DESCRIPTIOilS g RESULTS Set cmt. ret. on W.L. @ 11410'. RIH w/stab in & engauged (sand) ret. @ 11410'. Sqz'd perfs f/11430' to 11432' for isolation B20' w/50 sxs. C1 "G" w/1.5% D-19, .5% D-31 & .1% D-6. (Perf'd -11747' f/1i430' to 11432' broke down w/2000 psi & communicated w/ 11750' TD 11285' ETD (sand) 9 5/8" C. 7~20' 7"L. 7396'-&1747' 11751' TD 11585' ETD 9 5/8" C. 7 7" L. 7396' 1 12/5/79t 1175i' TD 11585 ' ETD 9 5/8" C. 7 7"L. 7396 '-! annulus). ' Initial rate 2CFM @ 1600 psi final rate 15CFM @ 1700 psi. Rev. clean & Pooh. RIH w/OEDP. Spot 28 sxs. sand on top of ret. @ 11410' w/water. P.U. 10 stds. & wait for sa to settle. 12/6/79 RI & tag sand @ 11275'. Pooh. RIH to perf. f/11264' to 1126 Tagged sand @ 11248'. Pulled W.L. RIH w/6" bit & C.O. sand to 11285'. Pooh. Perf'd 4 - ~" HPF above HB #4 for isolatio~ f/11264' to 11266'. RIH & set cmt. ret. @ 11210' on D.P. Sqz'd perfs f/11264' to (fill) 11266' for isolation above H.B. #4 w/100 sxs. C1 "G" w/1.5% B20" D-19, .5% D-31 & .1% D-6. Initial rate 11 CFM @ 3500 psi. ~11747' final rate 3 CFM @ 5200 psi. Rev. clean. Pooh. RIH w/6" mill & drill out ret. @ 11210'. C.O. cmt. to 11300'. C.O. sand to ret. @ 11410'. D.O. ret. @ 11410'. (No cmt. under ret. @ 11410'). RIH to 11585'. Circ. clean. 11751'TD 11585 ' ETD fill) 9 5/8" C. 7~20' 7"L. 7396 '-t.L 747 ' t 11751' TD 11207 ETD (r 9 5/8" C. 78 fill) 20' 747' ~-t) 20' Ran junk basket & 6" gauge ring -~stopped @ 11315'. Gauge ring & junk basket stuck @ 9020' on way out. Worked free. (recovered sand & a piece of junk off cmt. ~t. in junk basket). Reperf'd f/11430' to 11432' to re-sqz, below H.B. #4. Ran 6" bit & 7" scrpr, to 11585' & circ. clean. Ran 6" gauge ring and junk basket - stopped @ 11305'. Pulled out w/gauge ring. Ran 5.72" gauge ring & junk basket to 11500'. Set cmt. ret. on W.L. @ 11412'. RIH & sqz'd perfa f/11430' to 11432' thru cmt. ret. @ 11412' w/lO0 sxs. C1 "G" w/1.5% D-19, .5% D-31 & .1% D-6. Initial rate 10 CFM @ 600 psi, final rate 11 CFM @ 1700 psi. (NOTE: Had communication w/H.B. #4 perfs). Pooh. RIH w/6" bit & C.O. cmt. f/11343 to ret. @ 11423' DPM. Pooh. Set Baker cmt. ret. on D.P. @ 11207'. Sqz'd perfs f/11264' to 11266', 11294' to 11324' & 11332' to 11402' with 150 sxs. C1 "G" w/1.5% D-19, .5% D-31 & .1% D-6. Initial rate 12 CFM @ 3900 psi. Final rate 2 CFM @ 6000 psi. Rev. clean & Pooh. ., · . Alaska Oil & G¢_s Cons. C,-')rnmissio~i Anchoragc~ SHEET D PAGE Ui, IIOr! OIL CCI.?Ar,IY CLIFO IIA LEASE I' LL l.lO, FIELD D~TE 2O 21 22 23 25 26 27 28 29 30 12/7/7~ 12/8/79 12/9/7 12/10/ 12/11/t79 12/12/79 12/13/79 12/14/ 12/151 12/16/ 12/17/ 11751' TD 11207' ETD 9 5/8" C. 1175!' TD 112077 ETD 9 5/8" C. 7" L.7396' (ret) t820' (ret) 7820' -11747 ' 9 11751' TD 11207' ETD (ret) 9 5/8" C. 820' 7"L.7396'-11747' 79 11751' TD 11207' ETDt(ret) 9 5/8"c. F820' 7"L.7396'-I1747' 11751} TD 1 1i207' ETDI(ret) 5/8" C. ~820' 9 7"L.7396'-I1747' 11751' TD I 11207' ETD~(ret) 9 5/8" F820' 7"L.7396 I 11747' 11751' TD ! 11207' ETD (ret) 9 5/8" C. 7820' 7"L 7396'-L1747' 79 11751' TD 11207 ' ETD 9 5/8" C. 7"L 7396'- (ret) z820' L1747' t9 '11751' TD t 11207' ETq (ret,) 9 5/8" C./7820 .7"L 7396'-11747' 79 11751' TD 11207' ETI 9 5/8" C. 7"L 7396' 79 11751' TD 11207' ET! 9 5/8" C. 7 "L. =, ~6~ ~ Al.s. ska Oil & G~ DETAILS OF OPEPATION$, DESCRIPTIOilS g RESULTS Mill out ret @ 11207'. C.O. cmt. f/11209' to 11423'. Mill on ret. @ 11423' & ret. started moving dwn hole. Milled on ret. & cmt. to 11592'. Pooh for new mill. RIH & mill ret. & cmt. to 11600'. Pooh. RIH w/6" bit & 7~ csg. scrpr. Circ. clean @ 11600' & x-over to FIW. Spot 65 bb!s. of 6% KCL - 2 PPB "XC" & 20 PPB safe-seal on btm. Pooi Perforated 4 - ~" HPF using 4" csg. guns, N.B. #4 f/11402' to 11332'. Perforated 4 - ~" HPF using 4" csg. guns, H.B. #4 f/11324' to 11294', G-4 f/10708' to 10668', & G-3 f/10645' to 10620'. Ran gauge ring to 11100'. Set Baker "F" perm. @ 10850' on W.L. RIH w/seals on D.P. & test pkr. @ 10861' DPM. Running dual 3%" x 2 7/8" comp. assy. Ran dual 3½" x 2 7/8" Comp. Assy. Fourth GLM on L.S. hung up @ liner top - wOrked into liner after 1~ hrs. Tbg. Assy. stopped @ 10840' - only 10' above perm. pkr. @ 10850'. Pump~ down L.S. & broke circ. w/250 psi - confirming that seals not in perm. pkr. Picked up 20" to work pipe & it wouldn't go down. . . Finish Pooh. Found 1%" tubing parted above dual pkr. & left 2.04' of 1 ~" tubing in hole. RIH w/8½" flat-bottomed mill. RIH w/8~" flat-bottom mill & tagged liner top @ 7396'. Pooh. RIH w/6" flat-bottom mill & tagged prod. pkr. @ 10847'. (3' high) - Had slight bobble on weight indicator @ 10550'. Poo} RIH w/seal assembly on D.P. Stabbed into pkr. 5 times but had to work it each time. Test to 1000 psi - OK. Pooh. RIH w/B.O, shoe & pkr. picker. Repair brake water cooling pump. Burn over pkr. @ 10850' & recover. RIH w/7" csg. scraper on 6" mill. (ret) 7820' 11747' .. · . RIH to 11500'. Circ. w/FIW'& Pooh. Rigged up Dresser Atlas & R!H w/6" gauge ring & junk basket to 11150'.. Pooh. RIH w/Baker 7" Model "F" pkr. & set @ 10850' DIL. Rigged down Dresser Atlas. RIH w/seal assembly on D.P. & tested pkr. @ 10850' to 500 psi - OK. Pooh. · · Rigged up to run dual completion assembly. (ret) z820' Completed running dual Cubing strings & hung off on DCB spool & CIW tubing hanger. Tested prod. pkr. @ 10850' with 500 psi - OK. Rigged up Macco & RIH & set plug in."N" nipple in S.S. @ 10560'. Set dual hydraulic pkr. @ 10522' 'w/2200 psi. Pulled plug out of nipple and tested pkr. to 500 psi - OK. Pooh w/plug. Cons. Commission OIL CEI'?AI',IY OF CALIFORrlIA ~ELL ~SE IELL IlO, FIELD BATE 31 32 33 12/18/7 12/19/7 12/20/7 11751v TD 11207' ETD 9 5/8" C. 7 11751' TD 11207' ETD 9 5/8" C. 7 11751' TD 11207 ' ETD 9 5/8" C. 7 ret) 20' ret) 20' ret) 20' DETAILS OF OPEPATIONS, DESCRIPTIOilS g RESULTS Pooh w/"N" plug. Rigged down Macco. Install BPV's and remove BOPE. Landed and tested CIW dual ~ tree. Put well on production. Lay down 5" drill pipe. Prep. rig for turnaround to Leg #3. Release rig from G-8 @ 2400 hrs. 12/20/79. Fdrm 10-403 REV. 1-10-73 Submit "1 ntentions" 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 prol)osals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L ~ GAS r"-I WELL IL:.~l WELL OTHER NAME OF OPERATOR Union 0il COmpany of California 5. APl NUMERICAL CODE 50-133-20085-01 6. LEASE DESIGNATION ANO SERIAL NO. ADL 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 6247, Anchorage, AK 99502 G-8RD , 4. LOCATION OF WELL At surface Cond. #45, Le9 #2, 1874' N and 1382' W from SE corner of Sec 29, 19N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RT. 99' above MSL Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, R13W, SM 12. PERMIT NO. 78-45 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF g---J PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Reperforate existing intervals SUBSEQUENT REPORT OF: WATER SHUT-OFF E~ REPAI RING WELL FRACTURE TREATMENT~.~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Coml31etlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~etails, and give pertinent dates, Including estimated date of starting any proposed work. We propose to reperforate the following intervals- B-~ ~., ] 1102 32 B-4 11294 - 324' 11332 - 402. Additional intervals will be added in Bench 2 from 11132 - 11182 and in Bench 5 from 11431 - 11441 and 11478 - 11498. 16. I hereby certlfy_the~,the foregoing Is true and correct ¢.. --~- "~.., .-'-'----.~ ~,L-~------ District Engineer SIGNED C.H. CASE' ._ TITLE (This space for State office) A) · ~ APPROVED BY T IT LE~. See Instructions On Reverse Side DATE DATE 10/1/80 Approved -Cop~ J~eturne¢~ LONG STRING 1. 3 ½" Otis DK Safety Valve - 2. 3 ½" Camco KBUG GLM- 1991' " - 3333' " - 4557 ' " - 5500' " - 6209' " - 6804' " - 7256' 3. X.O. 3 ½" Butt x 2 3/8" Butt-7323~ 4. 2 3/8" Otis ~44 GI~i- 7647', " - 7998 ' " - 8378 ' " - 8724' " - 9073 ' " - 9421' " - 9769' " -10091' " -10447' 5. 2 3/8" Otis "XA" Sleeve-10483' 6. Baker Duel Packer -10521' 7. 2 3/8" Otis "~iA" Sleeve-10562' 8. " -10817' 9. Baker Seal D,~,sy - i0856', i]i.0L[ 2 3/8" Otis-'X" Nipple- 10899' 2 3/8" Mule Shoe - 10931' SHOR~ STP. ING A. 3 ½" Otis DK Safety Valve - 285' 5 'B. X.O. 3 ~" Butt x 2 7/8" Butt- 318' 6 C. 2 7/8" C~co KBHG GI2~ - 2018' 7 " - 3272 ' " - 4572' · " - 5795' " - 6851' 8 Do X.O. 2 7/8" Butt X 2 3/8" Butt-7324'9 E. 2 3/8" C~mco k~ GLM- 7750' 10 ·. " - 8501' i1 " - 9107 ' " - 9617 ' " -10055 ' " -10433 ' F. 2 3/8" Otis "XA" ~Sieeve - 10471' G. Baker Duel Packer - 10522' H. 2 3/8" Otis. "N" Nip~m_e- 10560' DAF~ '~':'~-8 W.O. . 12/79 UNION OIL COMPANY O~ CALIFORNIA 13 3/8" Casing- 3103' 9 5/8" Window - 7820'-7885' G-3 Sands 10620'-10645' G-4 Sands 10668'-10708' Hemlock B-1 11058'-11078' H~mlockB-2 11102'-11132' Hemlock B-4 11294'-11324' and 11332'-11402' Baker Cmt. Ret -11207' 7" Liner 7396'-11747' D RA'~FN ~ AtP'D. DATI~ SHEE'~$ j ~HEE'I' January 24, 1979 UNION OIL CO. OF CALIF. Post Office Box 6247 Anchorage, Ak. 99510 Re: G-8 RD #2 Gentlemen: 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\ ^ Division of HALLIBURTON Company 2400 West Loop South, R O. Box 22605 Houston, Texas 77027 A/C 713 671-4800 WELL DATA SUMMARY COMPANY UNION OIL CO~PANY OF CALIFORNIA ADDRESS Anchorage, Alaska REPORT FOR MR. WELL NAME & NO. G-8 RD #2 STATE COUNTY Alaska Kenai CONTRACTOR PARKER ADDRESS REPORT FOR MR. FIELD T .B .U. DESCRIPTION OF LOCATION Greyline Platform IMCO WAREHOUSE X Kena i WE L L DATA DATE SPUDDED 7/5/78 TOTAL DEPTH 11,750 DATE TD REACHED 7/28/78 CSG. SIZE 9 5/8" CSG. SIZE 7~ CSG. SIZE O.D. O,U, FROM TO 0'_ 7,396' FROM TO 7,396'_ 1.1,747' FROM -- TO HOLE SIZE FROM -- HOLE SIZE FROM 8 1./2" 7,828_~ HOLE SIZE FROM -- TO TO TO O,D. TOTAL DAYS CSG. SIZE FROM TO HOLE SIZE FROM TO O.D. BITS: NUMBER AND SIZE 23 - 8 1,/2" MUD UP DEPTHS 7,396~ TYPE MUD XC & GEL IN FILTERED INLET WATER COMMENTS No major problems on this job. Maintained flow properties by additions of prehydrated Gel to Filtered Inlet Water. 1.1 , 750 ' Lucian Abernathy/dd IMCO REPRESENTATIVE MCO FORM 509 COST SUMMARY P.O. NUMBER TOTAL DEPTH A Division of HALLIBURTON Company 2400 West Loop South, P. O. Box 22605 Houston, Texas 77027 A/C 713 622-5555 DATE PRODUCT UNITS ~5.00 SIZE t '...,' i '3 16 C; L ',:', =nLi:5 ~6AL AMOUNT 1707~C i CO SERVICES RECORD OF DRILLING MUD TESTS TON OIL COMPANY w~ ~A~E & ~O. ADivisi0nofHALLIBURTONC0mpany }--8 R, O, Houston, Texas 77027 A/C 713 671-4800' CASING HOLE SIZE NO. BITS NO. DAYS --APl STATE COUNTY WELL S/T WELL 9 5/8@ 7828 Prev. set, o. I I I I I I I I , IMCO REPRESENTATIVE T,HCi~ Abe~nathy/T. Shambo @ FIELD COUNTY STATE @ ['RADING BAY COOK INLET AK X/C POI,YMER ¢o~^¢m~ s~. ~1 ~ ....... TYPE MUD ' @ 100o _ ~ ~ARKER DRILLING HT-HP SALT I CAKE METHYLE~I~ ~LUE WEIGHT YIELD GEL ALKALINITY ~ CALCIUM WATER t~8LJ CHLOR,DE J ION CONTENT , DA, DEPTH [] lbs/gel VISCOSITY ~ PLASTIC VALUE STRENGTH pH FILTRATE FILTRATE 32nd SAND SOLIDS OIL ~O0 [] ppm % VOL % VOL % VOL % VOL me/mi Ibs/bb 19 ft. ,,~]bs/cu ft sec VIS cps lbs/lO0 ft2 lOS 1OM mi TI~ IN. Pi Mf Pm E] gPg ppm 7-5 7910 Salt Ware:" ' I · 7-6 7910 64 140+ 20 40 2~50 7 15 3 1 .2 L700 TR NIL ..... Built 800 ~arre'.s Ge~/Wat r J(1.~0+ v:is) Di. spla,:e HoLe >egi~ m:~llin~,~ @ 7~20 I 7-7 7848 64 180 21 46 2~50 8.0 17.4 - 3 .1 .2 11000 200 NIL - - 99 - - Run re:ills i~2 & 3 in 1~olo ~i~h I I 7-8 7871 64 120 11 24 1~34 8.0 20.8 - 3 .1 .2 :1000 160 NIL 1 - 99 Run M:.ll #1526 c,~mple;e so,~t~on cemel:tt fr,>m 78:~0 to 78115 I 7-9 Build XC ml~d sy:;tem ~,~ix 4()0 Jba~:rels preh zdrat<.~d ge L ('[2pp'~) ~v/500 barr,~ls, f .lterl~d. , in .et water & wei ;hr u~ ~;o ~0 - adde~i 110 .~X (l'.~pb) ~oda fish t,> F]:esh, vat,~r. · I 7-10 7820 6~ 30 8 14 1:~21 0.0 17.2 3~.8 3 .15 0000 480 NIT, - ~5 3 15 Addin; 50 ~arre s pr~hydr~[t{d ,~el + 1/2 >pb X¢~ pOl ~ma]: Fr,~sh~vater in 7-11 78130 70 40 19. 18 ~1~ 9~0 19..0 34.0 3 15_.0 0g00 480 Tlt 5 - ~5 3 15 I)ispl:[eod ~ole ,~ith :~C sy~,~tom :rear w±th 1./9. l>pb X~ a~d . - pl>b. D]~'±spa{: S.B Add Fres~wator - Dri 11 .ng ~ 8.5,~10.7 32.4 2 .2 0800 5t30 z t3 - 04 g 15 7-12 8260 70 48 13 25 1~31 .1 Drill.ng al~ead -- add 50 b~[r~el~ ~ prel~ydra'~ed g~l to sy~tem - ~eede I 100 from stor~ge ( ~ote ~100 in ST()rage. I , 7-13 8560 70 54. 13 27 1~39 8.5~0 8 !32.'4 2 1 2 ~2200 520 __1 I .... 2 6 94 3 15 _1 6 - 94 3 5 L7 7-13 8624 70 50 10 21 1~35 8.15 11.4 31.2 2 .1 .5 .2200 520 .4 · Added 50 b:[rrel.,~ P-G, 1 du]-i~g )yna ])rill run :o coiatr,)l " ~" ~acto: . I I I I I I I I 1 I I I J'~0TICE: T,- if';' !t:. : ~i[~,J cJ("lt~ c:,,~,ta,ned hereof-, a,'}d ail .~te~;_:,~etal,cns a;:d/oz recommendations m:~:lo in com.~c:t,ofl ti,crew.th, whelher presented ~),a~Jy o, ,~r,ti~n FORM 514 liVlCO SERVICES ~ A Divisionof HALLIBURTON Company Lucian Abernathy/T. ~M¢O REPRESENTATIVE TYPE MUD Sham~'b X,/C POLYMER *X-C GEL DEP[H ft. 8712 8911 Desa] 8963 55 9088 9215 Dilu ,,~,, 9313 9360 9420 Abov 9559 Prac to m 9626 Hit Chlo RECORD OF DRILLING MUD TESTS CASING HOLE SIZE NO. BITS NO. DAYS ALKALINITY 31.6 .8 i thru centrifical COMPANY UNION OIL COMPANY WELL NAME & NO. G-8 R.O. #2 -l i APl ELL WELL ....... ST TE C UN FIELD COUNTY STATE CONTRACTOR R METHYLENE BLUE Ibs/bbl L7.[ L7.[ L7.E .7. E L7.[ L7.[ L7.[ t ky 3 17. he~('~ ~ ~ '~.,,,.; c~,. ha'.~ Lcc'n ca~ct.~ ;',:~:~ed a:~d con~dered, arid m~,~ be c~ed ,f the use so elucl:., Huwever, i~(~ gdararltecs ot tiny k ~c ~n~: Ih~d~ FORM 514. ilVlCO SERVICES ADivisi0nofHALLIBURTONC0mpany 2400 West Loop South, R 0 Box 22605 Houston, Texas 77027 A/C 713 671-4800 IMCO REPRESENTATIVE Lllc:iarl Abernath¥ TYPE MUD DATE ,978 __ 7-17 7-17 7-18 DE PI'H fi. 9714 Had 9727 9747 No 9863 Disc 9920 X-C GEL RECORD OF DRILLING MUD TESTS CASING @ HOLE SIZE NO. BITS NO. DAYS COMPANY UNION OIL COMPANY " ' ' WELL NAME & NO. G-8 R.O. #2 · WELL FI ELD COUNTY STATE Trading Bay Cook Inlet Alaska CONTRACTOR R PARKER METHYLENE BLI 10029 At 0148 A No 10180 Last M 180 Mill good 6.7 ity, 17 P 1.8 6.8 & j uz~k Ba'. · reaillng Ho e in FORM 514 UNION OIL COMPANY ,. DRILLING MUD TESTS ~,ELL NAME & NO.. ~~ ADivisiopolHALLlBURTONCompany G-8 R.O. ~2 2400 West Loop South, R O. Box 226051 ~.. Houston, Texas 77027 A/C 713 671-~ APl CASING HOLE SIZE NO. BITS NO. DAYS I STATE I COUN~ WELL WELL IMCO REPRESENTATIVE ~uo/~ue~u~ ~ FIELD COUNTY STATE _ ~ T~ADING BAY OOOK I~BET AK TYPE MUD ~ ~ O ~ CONTRACTOR Sec. T R -- -, ~ PARER ,,, ,., [ WEIGHT YIELD GEL HT-HP CAKE ALKALINI~ ~ SALT DAT~19 ~ DEPTHft ~ lbs/galVlSCOSl~sec PLASTICvis VALUE STRENGTH pH FILTRATE FILTRATE 32nd ~ CHLORID~ CALCHJMioN S SOLIDS OIL WATER METHYLENE BLUE ~ Ibs/cu ft cps lbs/100 ft2 10S 10M mJ 500 psin ~ ppm ~AND CONTENT , TEMPRUF IN. P~ M~ Pm ~ gpg ppm VOL % VOL % VOL % VOL me/mi Ibs/bbJ J ' I 7-22 10283 71 54 13 22 L2137 8.0 8.6 27.0 2 .1 .8 12100 680 1/8 6 - 94 3.5 'DrilLing ~ith ~otto~n bit h~le in good c~ndit~Lon b~il~ 150 b~rrel~ casing P:~ehyd~cated g~l (70ppb) using 3 pp'b. SA per 50 ba~r~ls - string 50 ba~els~ in sysgem. 10~) bar:,els tn st~>rage Adding i Drilling e,>n~n~e b~t ru. 50' some set up ~ hol~ no~ (bugton)-..,tr~n~ ~n ~rehy~r~ted gel ' ' D~spae S.h. ruining d~s~[t~r ~o keep up w~th ~as~ drill 7-24 108~0 72 5~ 14 24 [3~24 8.0 8.1 2~.5 2 .1 1.0 ~2200~ ~80 1/8 ¢.5 03.5 3.5 i7~ D~ill~ng ~[th bOgtom b~g - Bu~[g 50 Barrels p~ohyd,ated gel ~ string ia ~o ~ystem adding Er~spae S.B. 7-25 11072 72 54 14 27 15;42 8.0 8.2 2~.~ 2 .1 .8 12200 720 1/8 fl.~ - ~3.5 3.5~ Drilling - tr~p for bi~ ~ m~ke ~op~r on Blow ou~ prevent~er sguek - sg~ng ~n prehydrated gel + Drispac S.L. , ! I I I 7-26 11258 72 59 14 30 19~44 8.fl 8.5 26.8 2 .1 .8 ~12200 760 1/4 6.5 93.[ 4 17. DrSlling trip for b~t-bu~lt[50 barrels p~ehyd~atod gol string 30 5n sy~stem 20 ~n I I~0 8 8.2 2~.~ 2 0 .7 12200 800 1/4 ~ 5 ~3.[ 3.u~7. 7-27 1154¢ 72 50 14 20 15~ · I ~38 8.5 7.8 20 0 2 T~ .8 12200 80~ 1/~ 8 5 ~1 [ 20 7-27 11~04 72 ~5 18 20 11~ . · . 7-27 1172~ 71 58 14 28 17~t 38 ~ 8.4 2~.4 g T~ .~ 12500 ~ 1/~ 7.8 ~2.~ 4 20 Second muc cheek o~ :the day} shows ~:iseos~ty lump ~ the o~.d cf the Dr,s,pat Super Bo T~eatm{nt. Beached d~p~h of 11~50~ Total ~ud 7-28 1185- 82 ~5 15 31 17[ 4~ 8 7.8 24.8 2 TR ~ 12500 0~C 1/~ 8.5 Ol.[i 4 C~rcu~latec and eondSt~oned hole ~o~ log~ see~ndar~ g~l s~reteh extremely grag~l~ as it br{~ke 5~ec~ia~ely back ~o 23. ho}e ~n gc,od st.ape. I IMCO SERVICES RECORD OF UNION OIL COMPANY DRILLING MUD TESTS WFLL NAME & NO. ~~ A Divis,on of HALLIBURTON Company G8 RD#1 ' Houston. Te×as 77027 A~G 7~3 871-a800' CASING HOLF SI7[ NO. BITS NO. DAYS ^~1 SI^IF COUNIY WILt WELL 9 5/8 e 7820 Prev Set NO. I I I I I I I Shambo & Abernathy 7" ~ 1!_747 8~ 23 20 FIELD COUNTY STATE IMCO REPRESENTATIVE @ TRADING BAY~ COOK INLET~ AK. X-C/GEL @ ¢o~^c~o~ so~. ~ TYPE MUD , . 100o ~, ~ PARKER /~ SALT "'~ I GHT YIELD GEL HT-HP CAKE ALKALINI1W CHLORIDECALCIUM WATER METHYLENE BLU! DATE DEPTH ~_j-lb S/go I VISCOSIT~ PLASTIC VALUE STRENGTH pH FILTRATE FILTRATE 32nd ION SAND SOLIDS OIL CONTENT , 7'8 500 psi~ ,]~ ppm ppm % VOL % VOL % VOL % VOL me/mi tbs/ 19 it. [-Jlbs/cu ftsec ViS cps lbs/100 fl2 10S 10M mi TEMP__.._u.uF IN. Pi Mt Pm J [] gPg 7-28 11750 72 46 10 1.4 6 J24 8 10.2 29.6 2 1.0 _2000 9~0 4 8.5 0 91. 5 4 21 Above pit ~heck take,~ after Jbe,ng o~f bo'~tom ~or o's, er 19 ~ou:.~s lo r, ging A1 log~ wen'g without problem. ~ill ~'ondi-ion laud f,>r ca~ing ~fter gett ~ng on )ot':om I I 7-29 11750 72 55 13 23 1~39 8 9.2 27.6 2 TR 1.0 L2500 920 ¼ 8.1 0 91.5 4 21 1_ 8 5 0 91 5 4 21 7-2~ 11750 72 t34 1:3 :3 1~42 8 7.8 25.2 9, TR 1.0 ~2500 ~$0 ~ . . Circu'Latiol~ & c,)ndit ~on m~d',foJ: lin,~r Puli ~ou.b of ~o1~.. I I 1 7-30 11750 72 48- 12 24 1~;38 7.5 12.2 31.8 2 0 1.0 [3000 1000 ¥ 8.5 0 91.5 4 Ran 1Lner ,vith ~o pr,)blem Jci:cula'bion prior to c~me~tin.~. Top (>f ii]er a- 7395 I , : ~ 8 5 0 91 5 4 7-30 11750 72 47 12 14 11~26 7.5 12.4 31.4 2 0 1.0 [3000 1000 ¥ . . Waiti ~g on Cement E ~ T. L1,~65'? -- 2 ~ ' 7-31 11747 71 40 9 4 0 ~ 7 11 29 3 . .95 [2000 240 ¥ 7.8 0 92.2 3.5 [7 No Ce:aent [n O 5/8 ¢:~,sing w~ll pres:~ure ~est ~efor~ ¢leanLng 7" l~nes. ~ ~ 7 8 0 92 2 3 5 L7 7-31 1'17471 71 38 5 5 0I 4 12 30+ --- 3 ~, 7 1.0 [2000 1000~ ¥ . , . Squee,~e t°'o of Liner : ~ 6 8 0 93.2, 3 ~ 8-1 11747 70 35 6 13 0J 2 12 30 -- 3 .7 .95 L2000 1040, ¥ . .,. Good Lap t.;st P~ll o, tt of h01e; wilL run in h,)le t,) c'Lean cub 7,, I ' ~ 68 0 93235 1' 8-1 11747 70 35 6 . 13 8 J20 12+ 30+ -- 3 [,3 1.8 [2000.~960' ¥ , . . · :t 68 0 93235 J l0 12+ 30+ -- 3 1 4 1 8 L2000 1000 ¥ . . . 8-2 11747 70 36 5 15 9, . . Clear,~d ou- to [1, 66 >,yand s~it,:hed ~ivia~ed m~d ov.~r go FLlt,~red inlet wate:~' in 2ase ~urther squee:~ing LS ne,;essa:.~ , ,{e~ea~ed f:?om Jl)b. I · I· ~ I I I [ I I I I NOTICE.: The ~nf(;rmut~,~u and data contained hereto and all mt~;rpretations and/or re~ommer, datlorm rnade in connection therevvJth, whether presented orally or writlen FORM hereto or e~:~e~here, have been carefully pcepared and considered, and may be used if the user so elects. However. no guarantees Of any kind are made et iRturid~:d, ~nd :~;ly ur,of tl~ereof agrees that IMCO SERVICES sbatl I~ot be liable for m~y damages, lOSS, costs or expenses resulting flOrfl the.use of same except where i iCO SERVICES , ~ RECORD OF '~o~^~¥ page DRILLIHG MUD TESTS ~,~, ~^~ ~ ~o. A Diwsion of HALLIBURTON Company Houston, Texas 77027 A/C 713 67t-~' CASING HOLE SIZE NO. BITS NO. DAYS APl STATE COUN~ WELL S T WELL IMCO REPRESENTATIVE 8hambo/'Aberna thy ~ F,[~g COUNTY STAT~ TYPE MUD ~~ CONTRACTOR WEIGHT YI[LD GEL HT-HP CAK~ ALK ALINI~ ~ SALT DATE DEPTH ~ ibs/9oIVISCOSI~ PLASTIC VALUE STRENGTH pH FILTRATE FILTRATE 32nd ......... ~ CHLORIDE CALCIUM WAfE~ M~fHYLENE ELUE lg ff ~ I~s/cu tt sec VIS cps lbs/100 ft2 10S 10M mi 500 ps~0 ~ ppm ~ON SAND SOLIDS OIL TEMP~IF IN. Pt Mf Pm ~ 9P9 ppm % VOL % VOL % VOL :~ ~o~ m~:/ml Ibs/I .... I ~ .viat ~d mu. ovo2 to ~1 :ere 1 i~let ~ater in c~se 1' ~rthe~ 21ear{~d out to 12.,~2 and ~tcl e~ a: ~quee::Sng i~ nec{~ssar ~. R~leas d Ifrr~m I I I I I I I I I I I I I I I I ~ · : : . I I I I I I I I I NOTICE'. The Informer*on and data contained harem arid ~]ll interpretations and/or recommendations made fl~:l¢:Iii or ~:l.t,t!wh£:re, hay(, [eer~ carefully, I:;rep:=r~!d ar',d considered, and rr,,ay be used if lhe user so elects. However, no guarantees of a~'W kind al:.; made or mt~ nde!d, ,.l~d ,,ny u~.er th~:re~,f agre~s tt.a', IMCO SERVICE'.S snail n()t be liz-,b!e for any damages, loss. costs or expenses resulting fronl the .use of s.~:;e ¢;x::u¢ t where d~i¢¢ ~,~ tl~) ~::,,.,¢ r~; :.:il:;(~:::::) (,,, ,,,tiff;ti n,t.%conduct ~f ?C,{) fi:~f!VIC:E:S or its a,-:.!nts ~rl the m~:!>aration -,. ,¢r.-_iRA. D!NG_BA_Y..IINTT STATE..V,'ZL[, NO..G_-.8RD _ ,,'.,: %. )la .... __ . ~ ::l£r,t) .~.JLgZHJJR._~VFR FTFLn_. __ LOCATiO:~_liOnd~ctnr #45 Leg Ro.o_m #2 __Grayling Platform 1874' Nor_\ii & 1832' West of ~orn of Sect. 29 T9_.N R11W SM. - ADL' 18/30 · SERI.M~ NQ860,~ I VU T.¥.D? PERMIT ~;0_, 78-45 TAD. '11750' MD DEVIATION (B.H.L.) , . I~AC~IO~/,. ..... Spt.ti) i.~,,\TI,7/10_~78 COStP. DA'r],,8/19/78~. CO: ,'t',: ..". CTO i.: Z A~KER I: ~W~C TY[" ...... ,',U,,,[- 1320 National ELb;VA'I'IONS: V,".Vi'k,i~ 131':Fi'i[ 125' /~// ILT. TO OCEAN FLOOR 224' ~.T. TO NILI.W 99' R.T. TO DRILL DECK __1.9.30' wATSON GRAHAH ltl T. TO PnOD CT P ' J e '5' COMPANY ENGINEER SIZE t V.'E[GHT I T?iEE.\D i GRADE l_,_.p,J,:~._T}{. REt:ARKS 2--~-m- ~/2" wa~i~-P-i pe ' 3bo .... i ...... "G" 'w/ Additives ~'C'-' /b~ Buttress J-55 '589' ~'Cm~'d w/ 1200 sxs "G" 13 3/8" 6!# Buttress J'L55 3103' '*Cmt'd w/'2300 sxs w/ Additives -_9 3/8" 43 1/2'& Buttress N-gO ,., 7820' *Cmt'd w/ 1500 sxs - SHUk a i800 sxs -DV 43# "G" w/ Add'.ig~ves. 9 5/8"' win,dow 7"82.,0"to 788-!_, __ __32L-__-Z9.&~ glittrogg I N-80 , F/11747 *Cmt'd w/ 830 sxs "G" w/ Additives } ;o 7396' *SEE. HISTORY-FOR CEMENTING DETAIL " P~;Rc OR,~Tx~'IG RECORD 8/3/781 11264 to_ 11266! 11623 -' t _8/8/78 10668 to 10708111230 8/9/Y8 -' ] 8/12/78 8/12/78 8/13/78 NOTE': I 10620 to 10645f 11230 11332 to 1140'2 11623 11294 to 113-24I 11623 10668 to 10708 111623 ISOLATION & ~'QUEEZE 'sqz'"O 'w/ 100P~J~(~t'xxLp°-IU2=tq:L PRODUCTION PRO~C~ i ON PROUUC~iON PRODUCTION PRODUCTION ~ G-4 ¸ Hemiock Bench '#4 Hemlock Bench #4 'G-4 I · G-8 ORIGINAL ~ELLBORE ABANDONED F/ 788~'j~'ALL Pg~<FS iN ORiGiNAL WELL SQZ:D THRU RET SET C~ 10684' i ' INITIAL PRODUCTtO~I ' ~ - _ . ~ - , ...:: - , ..... ~_..~. .~ , ........ ,,,~>~-,J Short String' "207. t 28% I ,, [ .... I ' ~i &t-"/ t k. I1~11 . j .' [Z18/7E Lonq Strinq 1361 j 5,% J ....... Hemlock- ~I ..... ' TYPE:, ,,../; · CASING HEAD:_SChaffer KD 12" 30'OD_psi w/ 2I,',C~m, eron, ,Valves S,O.W. -, CASING HANG,,.R._ Schaffer KD 12" - 9 5/8" M6del KD' KS Slips 13 3/8I', CASING SPOOL: - · TUBING HEAD:~, Cameron DeB 12" 300~ ~si x 10" '5000 psi · TUBING I[ANGER: Dual Cameron 3 1/2" TUBING IIEAB TOP: 3 1/2" EUe .< · MASTER VALVES: CiiRt<.r., ,. ,.,. ,.,:,.:,'e TRI:'.I,: TOP C()NN,:_3_ 1/2" EUe · ,o JHIO!'I OIL CS CALIFO IIA I',ELL I:ECO ,LD LEASE TRADING BAY UNIT STATE I'~LL ~I0, G-SRD FIELD McARTHUR RIVER FIELD DATE I 7/2/78 12,175' TD 7910' ETD (cmt ret) 13 3/8" csg 93103' 9 5/8" csg @I0,965' (381434) 2 7/3/78 3 7/4/78 12,175' TD 7910'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" csg @10,965' (381434) 12,175'TD 7910'ETD (cmt ret) DETAILS OF OPEP~TI~NQ, DESCRIPTIG~IS & RESULTS Commenced operations on TBUS G-8RD @00:01 hrs 7/2/78 Skidded rig from TBUS G-12 RD to G-SRD and RU. Loaded tb§ w/FIW Pulled ball valve from 307'. Opened "XA" sleeve @10,731' W/W.L. Stuck W.L. too! @9000' while pulling out. Worked free. Pulled W.L. tools out of hole. Spotted 50 bbls Safe-Seal, Dril-S pill across perfs. Removed X-mas tree. Installed 12" 3000 psi BOPE & tested to UOCO specs. PUlled tbg out of perm pkr @10,762'. Closed hydril & pumped 500 bbls of oil cut water ~ut of annulus. Pooh laying down 4 1/2" tbg & prod equip. RIH w/8 1/2" bit & 9 5/8" csg scraper. CO to pkr @10,762'. Pooh RIH and set cmt ret_~10_~684' on 5" DP. ' Squeezed to abandon Hemlock perfs ~W/ 350 sx C1 "G" w/.75% D-31, .5% D-19 & .1% D-6 mixed ca 118 PCF. Broke down @3000 psi. Final press of 4800 psi. Pooh. Ran gyro 10,650' to 4 7/5/78 7/6/78 7/7/78 13 3/8" surface. RIH w/junk basket & gauge ring to 8500'. Ran 3103' 9 5/8" CCL from 8500' -6500. Perf 4 holes @7928' to 7930' csg @10,965' Set cmt ret on W.L @7910' ' (381434) ' · 12,175'TD Squeezed perfs from 7928' to 7390' w/ 200 sx C1 "G" w/ 7910'ETD .75% D-31 and .3% D-19 mixes @118/PCF. Broke down @10 CFM (cmt ret) & 3000 psi. Final press of 4600 psi. CIP @05'35'hrs 7/5/78. 13 3/8" csg Rev out. POoh. Perf 4 - 1/2" holes from Z~30' to csg @10,965' 7831' w/ 195 sx C1 "G" w/ .75% D-31% .3% D-19.--Broke down (381434) @3-~00 psi & 10 CFM. Final press of 4100 psi CIP @16'20 hrs 7/5/78. Pooh. ' 12,175'TD RIH w/bit & CO cmt from 7810' to 7835' & stringers to 7910'. 7910'ETD Conditioned mud @7910' for window. Pooh. RIH w/ Servco (cmt ret) section mell #1. Milled window in 9'5/8" csg 7820' to 7831'. 13 3/8" csg (11' in 5 1/2 hrs). Pooh. RIH w/mill #2 Milled window in 3103' 9 5/8" 9 5/8" from 7831' to 7835'. ' 7769'ETD (cmt plug). 13 3/8" csg 3103' 9 5/8" window 7820' 7885' Milled wi~d~ow in 9 5/8" csg from 7835'-7859' 7/8/78 7769'ETD (cmt plug) 13 3/8" csg 3103' 9 5/8" window 7820' 7885'. Drld 7859' to 7885'. (Mill #2 14' in 8 1/2 hrs, Mill #3 10' in 5hrs, Mill #4 9' in 5 hrs, Mill #5 11' in 4 hrs, Mill #6 10' in 3 hrs). Total window cut 65' from 7820' to 7885'. Pooh & LD Servco tools. 7/9/78 7769' ETD (cmt plug) 13 3/8" csg 3103' 9 5/8" window 7820' 7885'. RIH & equalized 100 sx of C1 "G" cmt w/ .75% D-31 & 10% sand thru open ended DP hung @7910'. Pumped 200 CF water ahead, 70 CF behind & displaced' w/ 690 CF of mud. CIP @02'10 hrs 7/9/78. Rotated "DCB" spool, installed & tested new "R" seal. Built up new mud. Tested BOPE as per UOCO specs RIH & tagged cmt @7722'. CO cmt to 7769'. ' D 0IL Cf CALIF0 'IIA WELL LEASE I',ELL Il0, FIELD DATE 10 11 12 13 14 15 16 7/10/78 7/11/78 7/12/78 7/13/78 7/14/78 7/15/78 7/16/78 7/17/78 ETD 7871'TD 45' Footage 13 3/8" csg 3103' 9 5/8" window 7820' 7885'. 8195'TD 324' Footage 13 3/8"csg 3103' 9 5/8''I window 7820' 7885. 846~'TD 270 Footage 13 3/8" csg 3103 9 5/8" window 7820' 7885' 8662' TD 197' Footage 13 3/8" csg 3103' 9 5/8" window 7820' 7885' 8963' TD 301' Footage 13 3/8" csg 3103' 9 5/8" window 7820 7885' 9215' TD 252' Footage 13 3/8" cs'g 3103' 9 5/8" window 7820' 7885' 9602' TD 387' Footage 13 3/8" csg 3103.' 9 5/8" window 7820' 7885' '9730'TD 128' Footage 13 3/8" cs 31031 9 5/~" window 7820' 7885' DETAILS OF OPEP~TIONS, DESCRIPTIO~IS & RESULTS WOC until 10:00 hrs 7/10/78. Polished off pl.ug to 7826'. Pooh. ~RIH w/ BHA #1 & Bit #1 for DD run #1. Oriented tool 900 right of high side w/ eye tool. DD from 7826' to 7871'. DD from 7871' to 7896'. Pooh. RIH w/ BHA #2 & Bit #3. Directionally drld from 7896'-8195'. RIH w/ Bit #4 on BHA #3. Directional ly drld 8 1/2" hole from 8195'-8340'. Pooh. RIH w/Bit #5 on BHA #3. Directional ly drld 8 1/2" hole from 8340' -8465'. Dir. drld 8 1/2" hole from 8465' to 8590'. Tripped for DD. RIH w/ DD, Bit #6 & BHA #4 for DD Run #2. Oriented DD 1100 left of high side w/ eye tool & DD from 8590' to 8662' in 4 1/2 hrs. Pooh w/ eye. Tripped for bit. -.- RIH w/ Bit #7 & BHA #5. Reamed DD run from 8590' to 8662'. Directiona!ly drld 8 !/2" hole from 8662'-8762'. Pooh. RIH w/ Bit #8 &"BHA #5. Directionally drld 8 1/2" hole from 8762' to 8963'. Pooh. RIH w/ Bit #9 & BHA #6. Directionally drld 8 1/2" hole from 8963' to 9215'. Pooh. RIH w/ Bit #10 & BHA #7. Directionally drld 8 1/2" hole from 9215' to 9329' Pooh. RIH w/ Bit #11 & BHA #8. Directionally drld 8 1/2" hoie from 9329' to 9602'. RIH w/ Bit #12 & BHA #9 (Worled thru tight spot @9360). Drld 8 1/2" hole from 9602' to 9714'. Survey. Pooh. RIH w/ Bit #13 on BHA #10 for DD Run #3. Oriented DD 85o left of high side w/ eye. DD from 9714'-9730'. SEF_L-F D P^ E UHIO!'I OIL COr.:?Al'.h' CF CALIFO IIA WELL I ,ECOtLD LEASE l IO, FIELD DATE ETD 17 7/18/78 18 7/19/78 19 7/20/78 20 7/21/78 21 7/22/78 Z22 7/23/78 · 23 7/24/78 24 7/25/78 25 7/26/78 9985' TD 255' Footage 13 3/8" csg 3103' 9 5/8" window 7820 7885' 10,164' TD 179' Footage 13 3/8" csg 3103 9 5/8" window 7820 7885' 10,188"TD 24' Footage 13 3/8" csg 3103' 9 5/8" window 7820 7885' 10,277'TD 89'Footage 13 3/8" csg 3103' 9 5/8 window 7820 7885' 10,535' TD 258' Footage 13 3/8" csg 3103' 9 5/8" window 7820 7885' 10,759' TD 224' Footage 13 3/8" csg 3103' 9 5/8" window 7820 7885' 10,994' TD 235' Footage 13 3/8" csg 3103 9 5/8" window 7820 7885' 11,211' TD 217' Footage 13 3/8" csg 3103' 9 5/8" window 7820 7885' 11,456' TD 245' Footage 13 3/8" csg 3103' 9 5/8" window 7820 7885' DETAILS OF OPEP~TIONS, DESCRIPTIG~IS & RESULTS Completed DD run #3 from 9730' to 9752'. Pooh. RIH w/ BHA #11 & Bit #14. Dir. drld 8 1/2" hole from 9752'-9985'. RIH w/ Bit #15 on BHA #12. Dir. drld 8 1/2" hole from 9985' to 10,141'. Pooh for DD Run #4. RIH w/ Bit' #16 on BHA #13. Oriented DD 950 left of high side w/ eye & DD from 10,141' to 10,164'. DD from 10,~64'-10,188' (Completed DD Run #4 from 10,141' to 10,188' 47' in 5 hrsi. Pooh. Left 2 cones in hole. RIH w/ BHA #14 & junk mill. Stuck string going in @9926' Worked free after 3 hrs. Pooh. RIH w/ BHA #15 & Bit #~7. Reamed tight hole from 9920' to 10,188'. RIH w/ BHA #16 & junk mill. Milled on junk from 10,188' to 10,190' (4 hrs). Pooh. RIH w/ BHA #17 and Bit #18. Dir. drld 8 1/2" hole from 10,190' to 10,277'. Drilled 10,277' to 10,283'. Bit #18,~mill tool~"SDGH" 94' in 5 1/2 hrs, 17 FPH). Pooh. RIH w/ BHA #18 & Bi~ #19. Dir. drld 8" 1/2" hole from 10,283' to 10,535'. Drld 10,535' to 10,626'. (Bit #19, Insert F-2, 341' in 20 1/2 hrs, 16.6 FPH). Pooh. RIH w/ BHA #19 & Bit #20. Dir. drls 8 1/2" hole from 10,626' to 10,759'. Dir drld 8 1/2" hole from 10,759' to ,1,0,897'. Pooh. R~H w/ Bit #21 & BHA #20. Dir drld 8 1/2 hole from 10,897 to 10,994'. (Bit' #20 F-2 Insert 273' in 16 hrs, 17 FPH). Dir. drld 8 1/2" hole from 10,994' to 11,211'. (Bit #20, F-2, 314' in 21 hrs, 15 FPH). Pooh. RIH w/ BHA #20 and Bit #22. Dir. Drld 8 1/2" hole from 11,211' to 11,456'. Pooh. S EET PAGE UNIOII OIL CCl.? '-ff OF CALIFORIIIA ¥, LL I' ECOED LEASE ¥, 11 I0, FIELD DATE 26 7/27/78 27 7/28/78 28 7/29/78 29 7/30/78 30 7/31/78 31 8/1/78 32 8/2/78 ETD 11,750'TD 294' Footage 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 11,750' TD 11,658' ETD (plug catcher 13 3/8" csg ] 3103' 9 5/8" window 7820'- 7885' 7" line! 7396'-11,747' DETAILS OF OPEP~TISNSo DESCRIPTIGilS ~ RESULTS RIH w/ BHA #21 and Bit #23. Reamed' from 11.365'-11,456'. Drld 8 1/2" hole from 11,456'-11,750'. (Bit #23 Smith F-2, 294' in 19 hrs = 15.47'/hr). Pooh. Ran DLL, Sonic and FDC-CNL logs from 11,735' (WLTD) to 7822'. 11,750' TD (9 5/8" window). Ran repeat formation tester. RIH w/ 11,658' ETD Bit #24 & circ & cond hole for 7" liner. Pooh. Ran (plug catcher 55 jts 7". 13 3/8" csg 3103 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' 11,750' TD 'Ran 49'jts 7" 29# N'80 buttress liner. Hung 7" liner w/ 11,658' ETD shoe @11,747-', FC @11,701' & plug catcher @11,658'. TIW (plug catcher liner hanger @7424' & top of tie back sleeve @7396'. 13 3/8" csg Released from liner & cemented 7" liner w/ 630 sx C1 "G" 3103' 9 5/8" cmt w/ .8% D-19, .75% D-31, .3% A-2 & .1% D-6 followed by window.. 7820' tail slurry of 200 sx Cl "G" w/ 1.2% D-19, .1% D-6. Pumped 7885' 7" line 200 CF of water ahead & displaced w/ 1659 CF of mud. 7396'-11,747' (plugs didn't bump). CIP @13:10 hrs 7/30/78. Pooh. 11,750' TD 11,658' ETD (plug catche 13 3/8" csg 3103 9 5/8" window 7820' RIH w/ 8 1/2" bit & 9 5/8" csg scraper. Tagged top of liner @7396' (no cmt). Pooh. RIH w/ Baker ret pkr w/ test valve & set pkr @7263'. Opened test valve & tested 7" liner lap - no good (had strong blow for 1/2 hr). Rev out 500 CF of formation fluid. Moved pkr to 7285' & sqz 7" liner lap w/..300 sx C1 "G" w/ .1% D-31 mixed 7885' 7" line @118 PCF. Initial rate of 30 CFM @1200 psi, final rate 7396'-11,747' of 15 CFM @2000 psi. CIP @15:33 hrs 7/31/78. 11,750'TD 11,658' ETD (plug ca 13 3/8" csg 3103' 95/8" window 7820' 7885' 7" lin 7396'-11,747 11,750' TD 11,623'ETD 13 3/8" csg 3103' 9 5/8" window 7820' 7885' 7" line 7396' - 11, Pooh and--LD sqz. tool. RIH w/ 8 1/2" bit & 9 5/8" csg scraper to 7000' and WOC. Tagged cmt at 7,353'. Drld firm cmt to top of 7" liner at 7396'. Circ out. Pooh. Ran Baker stimulating valve and set retr. sqz. pkr at 7364'. Opened tool for 1 1/2 hrs. Slight blow - dead in 3 min. 'Opened bypass. Rev. out 8 cu. ft. of rathole fluid. Test was dry. Pooh. R!H w/ 6" bits 3 - 4 3/4" drill collars, and 7" csg scraper. Tagged cmt at 7396'. Drld hard cmt from 7396' to 7695', stringers from 7695' to 7835' Ran to 8979'. Drld stringers to 9030'. · , Ran to 11,340'. Drld cmt from 11,340' - 11,623'. Circ btms up. Changed mud to FIW and pooh. RU DA. Ran CBL Signature logs 11,623'-7800'. RU scientific eye and ran gyro. S EET D PAGE UHICI'I OIL CCI'.:?AI'.h' r__,f CALIFOP 'IIA I',ELL I',ECOtLD LEASE WELL l IO, FIELD DATE 33 34 35 36 37 38 8/3/78 8/4/78 8/5/78 8/6/78. 8/7/78 8/8/78 ETD 11,750' TD 11,230' ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" line 7396'-11,747 11,750' TD 11,230' ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820' 7885' 7" lin 7396' - 11,747 11,750' TD 11,230' ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820' 7885' 7" line 7396'-11,747' 11,750' TD 11,230' ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" wi ndow 7820' 7885' 7" lin~ 7396'-11,747 11,750'TD 11,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820' 7885' 7" lin~ 7396'-11,747 11,750'TD 11,230' ETD ~:m't ret) 13 3/8" csg 310.3' 9 5/8" window 7820' 7885' 7" line 7396 ' - 11,747 DETAILS OF OPEP~TIONS, DESCRIPTIO~IS & RESULTS Ran gyro survey. Perf 2-HPF from tl,264' to.11,266' Ran gauge ring & junk basket to 11,500. Set Baker cmt ret on W.L. @11,230'. RIH w/ 3 1/2" stinger on 5" DP & stab. into ret @11, 230'. Attempted to test annulus above ret., took fluid. Sqz perfs below ret. w/ 100 sx C1 "G" cmt w/ .75% D-31, .5% D-19, .1% D-6. (Broke down perfs w/ 3500 psi, initial rate 8 CF/min @3000 psi. Final rate 5000 psi @2 CF/min. CIP @17:35 hrs 8/3/78. RIH w/ 7" sqz. tool in 5" DP & set @ 7446'. Tested annulus abov~ tool to 2900 psi - o.k. Located & squeezed hole @9017' in 7" liner w/ 200 sx C1 "G" cmt w/ .75% D-31, .5% D-19, & .1% D-6 (initial rate 4 CF/min @3500 psi, final press. 5000 psi). CIP @06:35 hrs 8/4/78. Pooh w/ sqz tool. RIH w/ 6" bit & 7" scraper. CO hard cmt from 8860' to 9025'. Press. tested hole in - 7" @9017 w/ 3000 psi - no test. Pooh. er RIH w/ Baker sqz tools & set @8788'. Squeezed hole in 7" @9017' w/ 150 sx C1 "G" w/ .75% D-31, .5% D-19, & .1% D-6 (final press 3500 psi)'. CIP @05:00 hrs 8/5/78. Pooh w/ sqz. tools. RIH w/ 6" bit & CO cmt from 8854' to 9055'. Pooh. RIH w/ Baker test tools & set same - '@8778'~ Put 1100 psi gas cushion on DP. Opened test valve & bled off gas to dry hole in 7" @9017'. Had light blow for 10 min., dead remainder of 1/2 hr. test. Press. tested hole @3500 psi for 30 min - o.k. Pooh w/ test tools. RIH & set Baker Midel FB-1 perm. pkr on W.L. - @10,475' (DIL meas.). r Completed running 3 1/2" tbg. Landed in C.I.W. D.C.B. spool w. M.S. @10,558', "X" @10,527', Loc. Sub @10,4841, "XA" @10,451"& B.V. @319'. Removed BOPE Installed & tested to 5000 psi C.I.W. single 4 1/2" tree. Vamped flow & gas lift lines. Commenced lifting FIW from _annulus at 2100 hrs 8/7/78. Completed lifting annulus dry to 10,414'. RU D.A.W.L. & perf 4 - .32" HPF from 10,738' to 10,668' w/ well on gas lift. Commenced production test @22:00 hrs 8/8/78. L SE OIL CCFP2 'h' OF CALIFOP 'IIA I ~'~pL~ · I' ' LL I0, FIELD DATE 39 4O 41 42 43 44 45 8/9/78 8/10/78 8/11/78 8/12/78 8/13/78 8/14/78 8/15/78 ETD 11,750'TD 11,230' ETD (cmt ret) 13 3/8" csg 3103 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' 11,750' TD 11,230' ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' 11,750' TD 11,230' ETD (cmt ret) 13 3/8" csg 3103 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' 11,750' TD 11,623' ETD 13/3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' 11,750'TD 11,623' ETD 13 3/8" csg 31031 @ 5/8" window 7820'- 7885' 7" line 7396'-11,747': 11,750'TD 11,623' ETD 13 3/8" csg 3103' 9 5/8" window 7820' 7885' 7" line 7396'-11,747' 11,750' TD 11,623' ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' ~No, DESCRIPTIOilS ~ RESULTS DETAILS OF OPEP~TI~ ~ Cont. Prod. test unitl 10:00 hrs 8/9/78. R.U.D.A. W.L. & Perfed 4 - .32" HPF from 10,645' to 10,620' ("G-3 Sand"). REsmued Pro.d. test 14:00 hrs 8/9/78. S.I. @20:00 hrs 8/9/78 for press survey. R.I.H. w/ myers survey tools. -~ Ran press survey. Spotted 25 BBL Safe-seal pill across perfs. Filled annulus w/ FIW. Installed BPV. Removed tree, installed & tested BOPE. Sopt Dril-S pill across perfs. Pooh w/ 3 1/2" tbg. R.I.H. w/ pkr picker & rec 7" perm pkr @10,475'. RIH w/ 6" bit & drlg out cmt. ret. @11,230' & cmt. to 11.310'. R.I. to 11,623' & sopt Dril-S pill from 11,623' to 10,300'. Pooh. R.U.D.A.W.L. & perforated HB #4 from 11,332' to O.D. scg. guns. Reperforated "G-4" sand from 10,668' to 10,708' w/ 4-1/2" HPF using 4" O.D. csg guns. Run gauge ring to 11.,000'. Set Otis perm pkr @10,850'. Installed & tested dual tbg rams. Continued running dual 3 1/2" x 2 7/8" comp. assy. Stabbed into Otis perm pkr @10,850' w/ L.S. & tested to 1000 psi - o.k. Spaced out & landed tbg w/ L/S.M.S. @10,924'. Pulled ball valve dummy. Ran blanking plug to "XN" nipple @7298'. Couldn't test tbg. (Circ @ 8CF/min & 100 psi). Pooh w/ plug. RIH w/ shifting tool & checked "XA" - it was closed. RIH w/ blanking tool to test above "XA". Couldn't seat tool in "XA". Pooh. RIH w/ tbg BP, couldn't run in past 1st G.L.M. Pooh. RIH to retrieve bottom G.L.V. SHEET PAGE LEASE I' LL I0, FIELD DATE 46 47 48 49 8/16/78 8/17/78 8/18/78 8/19/78 ETD 11,750'TD 11,623' ETD 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' 11,750'TD 11,623' ETD 13 3/8" csg 3103" 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' 11,750' TD 11,623' ETD 13 3/8" csg 3103 9 5/8" window 7820'- 7885' 7" line 7296'-11,747' 11,750'TD 11,623'ETD 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" line 7396'-11,747' DETAILS OF OPEPATIONS, DESCRIPTiGilS & RESULTS Changed out G.L.V. #7 on S.S. RIH w/ W.L. & set plug in "XN" @7298' & attempted to test S.S. - no luck. Pooh. RIH w/ plug & set in "XA" @7217' & tested S.S. above "XA" to 1000 psi - o.k. Pooh. RIH w/ tbg plug & set in S.S. @7272', 13' below top of Otis trople Pkr @7259' & attempted to test S.S. - no luck. Released from TBG plug & pooh. Unlanded tbg & added a 3' pup to S.S. RElanded tbg & attempted to test S.S. - no luck. Unl.anded S.S. & pull S.S. up 20'. (Note' S.S. wa, s free of triple pkr as in the 20' P.U. It came free w/o any indication of shearing out of pkr, which requires 5OM# over tbg wt.) P.U. on S.S. and added an additional 7.35' of pups (11.15' total). Lowered S.S. & stabbed into triple pkr @7259'. Landed S.S. w/ 15,000 lbs from S.S. pkr. Press. up on S.S. & set pkr - tbg tested o.k. Recovered tbg plug from 7272'. Tested pkr @500 psi - o.k. Removed ball valve dummy from L.S. Installed B.P.V. Removed BOPE. Installed & tested C.I.W. dual tree @ 5000 psi. Installed & tested flowlines. Gas lifted FIW from annulus. Put well On prod. test. G-8L 8/18/78 1368 BPD .5%cut G-8S 8/18/78 288 BPD 28.0%cut Released rig from G-8RD @24-00 hrs 8/19/78. SHEET PAGE LEASE TRAn!NG BAY UNIT STATE U:,IIC[I OIL COF.P~J1Y CF CALIFOPCIIA ~"r- / I,ELL I,EL. Ot,LD l'i~bb [I0, G-SRD FIELD , McARTHtlR RfVFR FTFI n DATE FROM 11747. O0 11744.50 11702.27 11700.77 11658.96 11657.8I 11531.76 11516.65 7429.22 7423.67 7402.92 7395.67 ETD TO 11744.50 11702.27 11700.77 11658.96 11657.81 11531.76 11516.65 7429.22 7423.67 7402.92 7395.67 0 DETAILS OF OPEP~TIONS, DESCRIPTiO~IS & RESULTS LENGTH 2.50 42.23 1.50 41.81 1.15 126.05 15.11 4087.43 5.55 20.75 7.25 7395.67 7'l LINER DETAIL JTS. 1 1 3 99 DESCRIPTION Float Shoe % 7" 29# N-80 Buttress Float Collar 7" 29# N-80 Buttress Plug Catcher 7" 29# N-80 Buttress 7" 29# N-80 Butt. Pup 7" 29# N-80 Buttress T/W HYOR Hanger 7" 29# N-80 Butt~. Pup TIW TIE BACK SLEEVE LANDED BLEOW ZERO SF, EET D PAGE !'b, UHIO!! OIL CCF? C G CALIFCR IIA FLEASE TRADING BAY UNIT STATE l'i~LL ~I0, G-8RD FIELD McARTHUR RIVER FIELD DATE LONG STRING: FROM 10936.52 10935.52 10934.65 10904.79 10903.37 10873.60 10872.83 10862.00 10861.60 10860.76 10830.31 10826.76 10796.90 10790.35 10728.93 10610.41 10520.46 10513.90 10168.46 10161.90 9819098 9813.42 9470.35 9463.79 9152.04 9145.48 8807.39 8800.83 8465.71 8459.15 8062.39 8055.83 7688.67 7682.11 7591.12 7587.57 7279.70 7278.93 7271.08 7269.88 7239.50 7235.50 7204.85 -5197.60 6950.03 6942.78 6566.05 6558.80 6191.24 6182.69 TO 10935.52 10934.65 10904.79 10903.37 10873.60 10872.83 10862.00 10861.60 10860.76 10830.31 10826.76 10796.90 10790.35 10728.93 10610.41 10520.46 10513.90 10168.46 10161.90 9819.98 9813.42 9470.35 9463.79 9152.04 9145.48 8807.39 8800.83 8465.71 8459.15 8062.39 8055.83 7688.67 7682.11 7591.12 7587.57 7279.70 7278.93 7271.08 7269.88 7239.50 7235.50 7204.85 7197.60 6950.03 6942.78 6566.05 6558.80 6191.24 6182.69 5816.14 DETAILS OF OPEP~TICNS, DESCRIPTIOilS & RESULTS TUBING DETAIL LENGTH 1.00 .87 29.86 1.42 29.77 .77 10.83 .40 .84 30.45 3.55 29.86 6.55 61.42 118.52' 89.95 6.56 345.44 6.56 341.92 6.56 343.07 6.56 311.75 6.56 338.09 6.56 335.12 6.56 396.76 6.56 367.16 6.56 90.99 3.55 307.87 .77 7.85 1.20 30.38 4.0 30.65 7.25 247.57 7.25 3'83.98 7.25 367.56 8.55 366.55 JTS DESCRIPTION 2 6 3 11 11 11 10 11 11 13 12 3 10 1 1 12 12 12 2 7/8" Mule Shoe 2 7/8" 8RD to Buttress X-Over 2 7/8" 6.4# N-80 Buttress Otis 2 7/8" "XN 2 7/8" 6.4# N-80 Buttress 2 7/8" Buttress to 8RD X-Over Otis Seal Assy Otis Locator 8RD to Buttress X-Over 2 7/8" 6.4# N-80 Buttress 2 7/8" Otis "XA" Sleeve 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #1 2 7/8" 6.4# N-80 Buttress 2 7/8" Blast Joints 3 1/2" x 2.441" 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GKM #2 2 7/.:.81!-~ 6~'4# N-GO Buttress Camco'"KBUG" GLM #3 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #4 '" 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #5 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #6 2 7/8" 6.4# N-80 Buttress Camco 'IKBUG" GLM #7 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #8 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GL, #9 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #10 2 7/8" 6.4# N-80 Buttress Otis 2 7/8" "XA" Sleeve 2 7/8" 6.4# N-80 Buttress 2 7/8" Buttr. ess to 3 1/2" 8RD X-Over Otis RH-2 Triple Packer 3 1/2"'x 2 7/8" x 1.90" 3 1/2" 8RD to 3 1/2" Buttress X-Over 3 1/2" 9.2# N-80 Buttress 3 1/2" Otis 'IXAI' Sleeve 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #11 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #12 3 1/2" 9.2# N-80 Buttress Camco KBUG" GLM # 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #14 3 1/2" 9.2# N-80 Buttress U:'I!C~ OIL CCf.~ ~ C~= CALIFO?CIIA SMFFT D PAGE ~'b, .I_D'NSE I'~LL ~I0', FI ELD B~TE E-F9 DETAILS OF OPEPZ, TiCHS, DESCRIPTIC,~iS 2, RESULTS LONG STRING CC FROM 5816.14 5808.89 5435.29 5428.04 5038.77 5031.52 4643.03 4635.78 4064.22 4056.97 3250.93 3243.68 2138.03 2130.78 319.57 '317.07 39.50 38.50 NTINUED TO 5808.89 5435.29 5428.04 5038.77 5031.52 4643.03 4635.78 4064.22 4056.97 3250.93 3243.68 2138.03 2130.78 319.57 317.07 39.50 38.50 = 0 = LENGTH JTS DESCRIPTION 7.25 373.60 7.25 389.27 7.25 388.49 7.25 571.56 7.25 806.04 7.25 1105.65 7.25 1811.21 2.50' 277.57 1. O0 39.50 12 13 13 19 26 36 60 9 Camco "KBUG" GLM #15 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #16 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #17 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #18 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #19 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #20 3 1/2" 9.2# N-80 Buttress Camco "KBUG" GLM #21 3 1/2" 9.2# N-80 Buttress Otis Ball Valve 3 1/2" 9.2# N-80 Buttress CIW "DCBB" 3 1/2" Hanger LANDED BELOW ZERO OIL C= CA, LIFC, IA SMF q D PAGE" ,,LEASE TRADING BAY ,JN!T STATE FIELD - ' McARTHUR RIVER FIELD ~TE SHORT STRING: FROM 7311.77 7310.35 7280.45 7279.70 7270.80 7267.85 7232.49 7228.94 7196.94 7190.38 6976.72 6970.16 6382.93 6376.37 5662.80 5656.24 4714.26 4707.7O 3523.46 3516.90 2149.71 2143.15 363.89 363.24 331.48 328.98 39.50 38.50 TO 7310.35 7280.45 7279.70 7270.80 7267.85 7232.49 7228.94 7196.94 7190.38 6976.72 6970.16 6382.93 6376.37 5662.80 5656.24 4714.26 4707.70 3523.46 3516.90 2149.71 2143.15 363.89 363.24 331.48 328.98 39.50 38.50 - 0 DETAILS OF ~P~r~TI~',S, DESCRIPTICFIS ~ R~bULTo TUBING DETAIL LENGTH 1.42 29.90 .75 8.90 2.95 35.36 3.55 32.00 6.56 213.66 6.56 587.23 6.56. 713.57 6.56 941.98 6.56 1184.24 6.56 1367.19 6.56 ' 1779.26 .65 31.76 2.50 289.48 1.00 38.50 JTS DESCRIPTION 1 1 7 19 23 31 39' 44 60 1 9 2 7/8" Mule Shoe 2 7/8" 6.4# N-80 Buttress ., . 2 7/8" Buttress to 8RD X-Over Otis RH-1 Triple Packer 3 1/2" x 2 7/8" x 1.90" 2 7/8" 8RD to Buttress X-Over 2 7/8" 6.4# N-80 Buttress 2 7/8" Otis "XA" Sleeve 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #1 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #2 2 7/8" '6.4# N-80 Buttress Camco "KBUG" GLM #3 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #4 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #5 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #6... 2 7/8" 6.4# N-80 Buttress Camco "KBUG" GLM #7 2 7/8" 6.4# N-80 Buttress 2 7/8" to 3 1/2" Buttress X-Over 3 1/2" 9.2# N-80 Buttress 3 1/2" Otis Ball Valve 3 1/2" 9.2# N-80 Buttress CIW "DCBB" Hanger LANDED BELOW ZERO ,, FFT PAGE OIL 'I I T r"ll CAlL,FCic,IA LEASE TRADING RAY IINIT STATE I',~I,_L ilO, G-8RD FIELD McARTHUR RIVER FIELD ~TE SIDE STRING FROM 10831.64 10799.41 10791.34 10728.09 10609.87 10533,82 10521.45 10513.44 10182.91 10168.46 10160.71 9834.25 982O.80 9913.05 ,9486..91 9471.35 9462.79 9169.28 9153.04 9144.48 8821.95 8808.39 8799.83 8479. O0 8466.71 8458.15 8080.18 8063.39 8054o 83 7706.66 7689.67 7681.11 7294.61 7279.53 7271.08 7269.68 TO 10799.41 10791.34 10728.09 10609.87 10533.82 10521.45 10513.44 10182.91 10168.46 10160. ,71 9834.25 9820.80 9813.05 9486.91 9471.35 9462.79 9169.28 9153.04 9144.48 8821.95 8808.39 8799.83 8479.06 8466.71 8458.15 8O80.18 8063.39 8054.83 7706.66 7689.67 7681.11 7294.61 7279.53 7271.08 7269.68 7208.76 DETAT' o ,-,~, .L.~ OF OPE?2~Ti~r,S, TUBING DETAIL LENGTH 32.33 8.07 63.25 118.22 76.05 12.37 8.01 330.53 14.45 7.75 326.46 · , 13.45 7.75 326.14. 15.56 8.56 293.51 16.24 8.56 322.53 13.56 8.56 320.83 12.29 8.56 377.97 16.79 8.56 348.17 16.99 8.56 386.50 15.08 8.45 1.40 61.02 JTS 1 2 12 2 10 10 10 9 10 9 11 10 11 2 DESCRIPTIO~IS ~ RESULTS DESCRIPTION 1.90" 2.40# H-40 lORD Bull-Plugged Camco "KBUG" GLM #1 · ' '1.90" 2.40# H-40 lORD Blast Joint 1.90" 2.40# H-40 lORD Telescopic Joint Camco "KBUG" GLM #2 1.90" 2.40# H-40 lORD Telescopic Joint Camco "KBUG" GLM #3 1.90" 2.40# H-40 lORD Telescopic Joint Camco "KBUG" GLM #4 1.90" 2.40# H-40 lORD Telescopic Joint Camco "KBUG" GLM //5 1.90" 2.40# H-40 lORD Telescopic Joint Camco "KBUG" GLM #6 1.90" 2.40# H-40 lORD Telescopic Joint '" Camco "KBUG" GLM #7 1.90" 2.40# H-40 lORD Telescopic Joint Camco "KBUG" GLM #8 1.90" 2.40# H-40 lORD - Telescopic Joint Camco "KBUG" GLM #9 1.90" 2.40# H-40 lORD Telescopic Joint Camco "KBUG" GLM #10 1.90" 2.40# H-40 lORD Telescopic Joint Otis RH-1 Packer 1.90" lORD to 2 3/8" Butt. X-Over 2 3/8" 4.6# N-80 Buttress Bull Plugged and Perf'd. HUGHES TOOL COM- PANY has available the lilt RECORD ~:,.v41 ~ Ro~_~ ~ m~.l~:~':n. ~>:~: ~nS~ 0 ~ ~ 11 ~ q~M "~ ' "7" gUT WJN~0' ~'/ LINER PU~P POWER TYPE MUD ORILL PIP~ ~IZ~ TYPE O.D. ~ ~UM~R O,D, I,D. L~NGTH DRAWWORKS POWER -~ ~ 0 JOINTS COLLARS J ACCU~ WT. V~RT PU~P PUMP S P M MUD DULL. COND NO. SIZE MAKE TYPE JET SERIAL DEPTH FEET HOURS FT,/HR DRLG. I000 R P ~ OPER- ' FORMATION ~. 3gND IN OUT ~RS. LBS. DEV. PRESS ATtON REMARKS ...... " ~' ~' ~L~ "~%~ ~ ~ ' '' ,.:: ., , ' I '~..' : ;:.'= · . .. k J~ < .... C.~OI , --. ... ~ . ~ ,,, ~,., t, f:,h:,':,'~.~ ~8~:t ~ r .;'~ 5"C~~ 1:~ ~ ~..., D c'"0 -:-~,.., ,".: ..... .:: ':', ..... . ... following bulletins to assist you in getting your hole down in the shortest time and with the fewest bits: "Hydraulics for Jet Bits" "New Hughes Simpli- fied Hydraulics" "Rotary Drilling Bits" .. "How to get the most from Hughes Journal Bearing Bits" "Hughes General Cata- log" Contact your Hughes Representative. He will welcome the opportun- ity to work with you and will furnish you with the latest information on rock bits and drill- lng techniques for your area. Compliments of HUGHES TOOL COMPANY HOUSTON, TEXAS U, S. A. HTC 557 D HUGHES TOOL COM- TOOLI DRILL JOINTS COLLARS ACCUM WT. VCRt PUMP PUMP S P M MUD DULL. COND. NO SiZE MAKE TYPE JET SERIAL DEPTH FEET HOURS FT/HR DRLG. 1000 R P M OPeR- FORMATIO 32ND In OUT HRS. LBS. DEV. PRESS ATION ! 2 WT. VIS.IW.L. T B G OTHER REMARKS , ~ ' ..: ].... , · ..... , , · ,~ *- ~:... ':" "*'/" ':'"' " ~'gn' I I ;~. '4 ' :" :"';:::'":: ' I PANY has available the following bulletins to assist you in getting your hole down in the shortest time and with the fewest bits: "Hydraulics for Jet Bits" "New Hughes Simpli- fied Hydraulics" "Rotary Drilling Bits" "How to get the most from Hughes Journal Bearing Bits" "Hughes General Cata- log" Contact your Hughes Representative. He will welcome the opportun- ity to work with you and will furnish you with the latest information on rock bits and drill- lng techniques for your area. Compliments of HUGHES TOOL COMPANY HOUSTON, TEXAS U.S.A. HTC 557 D 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.) WELL L_J OTHER ~ NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR P.O. Box 6247 4. LOCATION OF WELL At surface Cond. #45, Leg #2, 1874'N & 1382'W from S.E. Cor., Sec. 29, T9N, R13W, S.M. '13. ELEVATIONS (Show whether DF, RT, GR, etc.) Rt 99' Above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20085-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. TBUS G-8RD 10. FIELD AND POOL, OR WILDCAT McAr thur River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, R13W, S.M. 12. PERMIT NO. 78-45 )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT Of: WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZlNG (Other) see below REPAI RING WELL ALTERING CASING ABANDONMENT* (NOTE= Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of ~arting any proposed work. In order to isolate the water entry in TBUS G-8RD, Graying Platform, the following work was performed: ---- l. 2. 3. 4. 5. e Moved rig over conductor #45, Leg #2, TBUS G-8RD and rigged up. Killed well, installed BPV's, removed tree, installed & tested BOPE. Pulled and layed down existing dual 3½" - 2 7/8" comp. assy. Retrieved perm. pkr. from 10,850'. Perf'd below H.B. #4 for zone isolation from 11,430' to 11,432' & sqz. perfs w/150 sx. C1 "G". Re-perf'd above H.B. #4 from 11,264' to 11,266' & sqz. perfs with 250 sx. C1 "G". Re-perforated H.B. #4 perfs 11,402' to 11,332', 11,324' to 11,294', G-4 10,708' to 10,668' and G-3 10,645' to 10,620'. Ran dual 3½" - 2 7/8" comp. assy. Installed BPV's, remove BOPE, install & test tree. Place well on dual "G" & Hemlock gas lift production. ~. 16. I hereby ~ that the foregoing Is true and correct (This~,la~ce for State office use) TITLE Dist. Drlg. Supt. DATE 1/18/8o APPROVED BY. CONDITIONS OF APPROVAL, IF ANY.. TITLE . DATE See Instructions On Reverse Side I I I I Il I I I Il I Ill I I I Il I I Ill · ... " " ~o~'~ ~ , I ~/~ c, , , , .~ ,. ~1~ ~ b ' . , . , c ~ 7, s~'- ~ ~' '~ i ~ a~/~""x~'' ~ ..... 8o~U ~ " i J J ' - -- · ~ , .~ ~ .. ~e{' c. ~%~ ~_[ _ - ,_ ~ . : ~ .... ~,.~, , ~ ~' ' ' '~,d~ toq~~ ; t t- --- UNION OIL COMPANY OF C~I~RNIA , Form No. 10-404 SUBMIT IN DUPLICATE RE'f. 3-1-70 ~' STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE © THLY REPORT OF DR iLL G AI D W©RK© ©pr:RAT OI $ 5. APl NUblERICAL CODE 6. LEASE DESIGNATION AND SI'.'RIAL NO. 1. 7. IF IND1AN'ALOTI'EE OR TRIBE NAME OIL ~"~X GAS V-'] WELL WELL OTIIER 2. NAME OF OPERATOR 8. L'NFF FARM OR LEASE NAME UNION OIL COMPANY OF 'CALIFORNIA 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 9. '~ ELL NO. G-8 RD 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM flOLE OBJECTIVE) 12. PERMIT NO. 31 32 33 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN ttOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTti SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE A. ND ANY OTItER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 12/18/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7920' Pooh w/"N" plug. Rigged down Macco. Install BPV's and remove BOPE. Landed and tested CIW dual 3½." tree. Put well on production. 12/19/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7920' Lay down 5" drill pipe. 12/20/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7920' Prep. rig for turnaround to Leg #3. G-8 @ 2400 hrs. 12/20/79. Release rig from 14. I hereby certify that the foregoing is true and correct SIGNED · TITLE DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-20085-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18730 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME UNION OIL COMPANY OF CALIFORNIA Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247, ANCHORAGE, ALASKA 99502 TBUS G-8RD 4. LOCATION OF WELL Cond. #45, Leg #2, 1874'N & 1382'W fr°m~S:E;~~ ' '~ ~;'C°r'~'i~i) Sec. 29, T9N, R13W, S.M. ~ ' '~ ~ ~ '~, .~ 10. FIELD AND POOL. OR WILDCAT McAr thur River 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, R13W, S.M. 12. PERMIT NO. A~,~l;a Oi~ & G'.:.~ ,,.,',,:.,. ,.,oi,,,~us~it,~ 78-45 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASI~j~{~I~i~MENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNI~ IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 11/18/79 11750' TD 11623' ETD (cmt) 9 5/8" C. 7820' Commence operation 00:01 hrs. 11/18/79. Moving rig f/Leg Room #3 to Leg Room #2. 11/19/79 11750' TD Moving rig f/Leg Room #3 to Leg Room #2. 11623' ETD (cmt) 9 5/8" C. 7820' 7"L. 7396' to 11747' 11/20/79 11750' TD Moving rig f/Leg Room #3 to Leg Room #2. 11623' ETD (cmt) 9 5/8" C. 7820' 7" L. 7396' to 11747 11/21/79 11750' TD Moving rig from Leg Room #3 to Leg Room #2. 11623' ETD (cmt) 9 5/8" C. 7820' 7" L. 7396' to 11747' 11/22/79 11750' TD Moving rig from Leg Room #3 to Leg Room #2. 11623' ETD (cmt) 9 5/8" C. 7820' 7" L. 7396' to 11747' 11/23/79 11750' TD Completed move f/leg room #3 to leg room #2, 11/23/79. 11623' ETD (cmt) Opened "XA" in L.S. @ 10827'. Pumped 120 bbl. pill of 6% 9 5/8" C. 7820' KCL w/2 PPB "XC" & 20 PPB Safe-Seal down L.S. Spot 80 bbls. 7" L. 7396' to 11747'/ across "G" zone perfs& 40 bbls. to Hemlock perf's. Filled annulus w/FIW. Pulled & layed down S.S. 14. ! hereby q~ that the fore~o}n~ue_and correct _ _ _ t l' .~I~]. [ , Dist. Dr±g. Supt. DATE SIG~E~~ a{, ~-e..t'_~ _.~--e~-~T,TLE 12 / 10 / 7 9 NOTL~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SUBMIT IN DUPLICATE Form No. 10404 REV. 3-1-70 ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL WELL GAS [---1 WELL OTHER 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. WELL NO. TBUS G-SRD 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 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 RESULq[~I~II¥~, fJQBSi JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITION .S~d~is't ~i rC~ · ,,JL,,~ii~':" i~ 11/24/79 11750' TD Attempt to pull pkr. loose w/L.S. - No luck. Jet cut L.S. 11623' ETD (cmt) @ 7127'. Layed down L.S. 9 5/8" C. 7820' 7" L. 7396' to 11747' 11/25/79 11750' TD Engauged L.S. @ 7127' w/O.S. Pulled O.S. off fish. Trip & 11623' ETD (cmt) redressed O.S. Engauged fish @ 7127'. Pooh w/L.S. (recovered 9 5/8" C. 7820' 1.6' of 9 5/8" csg. f/top of triple pkr. - damaged csg?) 7" L. 7396' to 11747' 11/26/79 11750' TD Completed laying down L.S. w/dip tube. FIH w/8¼" bit to 11623' ETD (cmt) top of liner @ 7396'. Circ. well clean w/FIW. Pooh. 9 5/8" C. 7820' (NOTE: 8~" bit ran in & out with no indication of damaged 7" L. 7396'-11747' pipe). Ran 8½" gauge ring - stopped @ 5227'. Ran 8 3/8" gauge ring to 7396'. Ran collar log f/7396' to 4500'. Collar log indicates damaged csg. @ 5227'. 10 11/27/79 11750' TD Wait on Dia-Log unit to run csg. inspection log - bad weather. 11623' ETD (cmt) 9 5/8" C. 7820' 7" L. 7396' to 11747' 11 11/28/79 11750' TD Ran Dia-Log 9 5/8" casing inspection log f/7396' to surface. 11623' ETD (cmt) Casing pitted f/+7396' to +6900'. RIH w/Baker retriev-a-matic. 9 5/8" C. 7820' Set sqz. tool @ 7--820' & te~ted 9 5/8" csg. above sqz. tool to 7" L. 7396'-11747' 2000 psi. Pooh. RIH w/Packer-Picker to 7" Otis perm. pkr. @ 10850'. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. rqr. m No. 10404 ?~t. 3-1-70 ' SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE O qTHLY REPORT DRILLI G 2. NAME OF OI'ERATOR UNI.ON OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE~ ALASKA 99502 4. LOCATIONOF~VELL Cond. #45, Leg #2, 1874'N & 1382'W from S.E. Cor., Sec. 29, T9N, R13W, S.M. 5. APl NUMERICAL CODE 50-133-20085-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18730 7. IF INDIAN'ALOT[EE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO, G-8 RD 10. FIELD AND POOL OR WILDCAT McArthur River Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, R13W, S.M. 12. PERMIT NO. 78-45 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTtt SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE ,&,ND ANY OTttER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 14 12/1/79 1'.5 12/2/79 16 12/3/79 11750' TD Set cmt. ret. on W.L. @ 11410'. RIH w/stab in & engauged 11285' ETD (Sand) ret. @ 11410'. Sqz'd perfs f/11430' to 11432' for isolation 9 5/8" C. 7820' w/50 sxs. C1 "G" w/1.5% D-19, .5% D-31 & .1% D-6. (Perf'd 7" L. 7396'-11747' f/11430' to 11432' broke down w/2000 PSi-& communicated w/ annulus). Initial rate 2CFM @ 1600 psi final rate ]5CFM @ 1700 psi. Rev. clean & Pooh. RIH w/OEDP. Spot 28 sxs. sand on top of ret. @ 11410' w/water. P.U. 10 stds. & wait for san, to settle. !1750' TD 11285' ETD (sand) 9 5/8" C. 7820' 7"L. 7396'-11747' RI & tag sand @ 11275'. Pooh. RIH to perf. f/11264' to 11266 Tagged sand @ 11248'. Pulled W.L. RIH w/6" bit & C.O. sand to 11285'. Pooh. Perf'd 4 - ½" HPF above HB #4 for isolation f/11264' to 11266'. 11751' TD RIH & set cmt. ret. @ 11210' on D.P. Sqz'd perfs f/11234' to 11585' ETD (fill) 11266' for isolation above H.B. #4 w/J00 sxs. C1 "G" w/1.5% 9 5/8" C. 7820' D-19, .5% D-31 & .1% D-6. Initial rate ll CFM @ 3500 psi. 7" L. 7396'-11747' final rate 3 CFM @ 5200 psi. Rev. clean. Pooh. RIH w/6" mill & drill out ret. @ 11210'. C.O. cmt. to 11300'. C.O. sand to ret. @ 11410'. D.O. ret. @ 11410'. (No cmt. under ret. @ 11410'). RIH to 11585'. Circ. clean. TITLE Dist. Drlg. Supt. ]/9/8o DATE NOT~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the' oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. i~0404 Rt_W. 3-1-70 · SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN.ALOTTEE OR TRIBE NAME i. o,L [~ GAS [2] WELL WELL OTIIER 2. NAME OF OPERATOR 8. L;NIT FARM OR LEASE NAME UNION OIL CO. OF CALIFORNIA 3. ADDRESS OE OPERATOR 4. LOCATION OF WELL 9. '~',i:LL NO. G-8RD 10. FIELD AND POOL, OR WILl)CAT 11. SEC. T. R. bi. (BOTTOM ttOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTll SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED IIOLE AaND ANY OTHER SIGNIEICANT CHANGES IN HOLE CONDITIONS. 17 12/4/79 11751' TD 11585' ETD (fill) 9 5/8" C. 7820' 7"L.7396'-11747' Ran junk basket & 6" gauge ring - stopped @ 11315'. Gauge ring & junk basket stuck @ 9020' on way out. Worked free. (recovered sand & a piece of junk off cmt. ret. in junk basket). Reperf'd f/11430' to 11432' to re-sqz, below H.B. #4. Ran 6" bit & 7" scrpr, to 11585' & circ. clean. Ran 6" gauge ring and junk basket - stopped @ 11305'. 18 .12/5/79 19 12/6/79 11751' TD 11585' ETD (fill) 9 5/8" C. 7820' 7"L.7396'-11747'. 11751' TD 11207 ETD (ret) 9 5/8" C. 7820' Pulled out w/gauge ring. Ran 5.72" gauge ring & junk basket to 11500'. Set cmt. ret. on W.L. @ 11412'. RIH & sqz'd perf: f/11430' to 11432' thru cmt. ret. @ 11412' w/100 sxs. C1 aG" w/1.5% D-19, .5% D-31 & .1% D-6. Initial rate 10 CFM @ 600 psi, final rate 11 CFM @ 1700 psi. (NOTE: Had communication w/H.B. #4 perfs). Pooh. RIH w/6" bit & C.O. cmt. f/11343 to ret. @ 11423' DPM. Pooh. Set Baker cmt. ret. on D.P. @ 11207'. Sqz'd perfs f/11264' to 11266', 11294' to 11324' & 11332' to 11402' with 150 sxs. C1 "G" w/1.5% D-19, .5% D-31 & .1% D-6. Initial rate 12 CFM @ 3900 psi. Final rate 2 CFM @ 6000 psi. Rev. clean & Pooh. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE J O THLY REPORT OF DRillL. NG WOR[(OYE OP RATIIO JS WELL WELL OTIIER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERACFOR 4. LOCATION OF WELL 5. AP! NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. L:NIT FARM OR LEASE NAME 9. '.:ELL NO. G-8 RD 10. FIELD AND POOL, OR WILDCAT 11. SEC. T. R. bi. (BOTTOM HOLE OBJECTIVE) 12. PE~RMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTtt, CHANGES IN ItOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTtt SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED tlOLE AND ANY OTllER SIGNIFICANT CttANGES IN HOLE CONDITIONS. 20 21 12/7/79 12/8/79 11751 ' TD 11207' ETD (ret) 9 5/8" C. 7820' 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' 7" L.7396'-11747' 22 23 24 12/9/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' 7"L.7396'-11747' 12/10/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' '7"L.7396'-11747' 12/11/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' 7"L.7396'-11747' 25 12/12/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' 7"L.73q6' - ]]7A7' 14. i hereby c~rtify that the foregoing is true and correct SIGNED Mill out ret @ 11207'. C.O. cmt. f/11209' to 11423'. Mill on ret. @ 11423' & ret. started moving dwn hole. Milled on ret. & cmt. to 11592'. Pooh for new mill. RIH & mill ret. & cmt. to 11600'. Pooh. RIH w/6" bit & 7" csg. scrpr. Circ. clean @ 11600' & x-over to FIW. Spot 65 bbls. of 6% KCL - 2 PPB "XC" & 20 PPB safe-seal on btm. Pooh Perforated 4 - ½" HPF using 4" csg. guns, H.B. #4 f/11402' to 11332'. Perforated 4 - ~" HPF using 4" csg. guns, H.B. #4 f/11324' to 11294' G-4 f/10708' to 10668' & G-3 f/10645' to 10620' Ran gauge ring to 11100'. Set Baker "F" perm. @ 10850' on W.L. RIH w/seals on D.P. & test pkr. @ 10861' DPM. Running dual 3~" 8" 2 x 2 7/ comp. assy. Ran dual 3½" x 2 7/8" Comp. Assy. Fourth GLM on L.S. hung up @ liner top - worked into liner after 1½ hrs. Tbg. Assy. stopped @ 10840' - only 10' above perm. pkr. @ 10850'. Pumpe down L.S. & broke circ. w/250 psi - confirming that seals not in perm. pkr. Picked up 20" to work pipe & it wouldn't go down. Finish Pooh. Found 1 ~" tubing parted above dual pkr. & left 2.04' of 1 ½" tubing in hole. RIH w/8½" flat-bottomed mill. TITLE _ DATE . NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conserv'ation committee by the 15th of the suCceeding month,unless otherwise directed. ~orm No." 10404 R~ ,". 3-1-70 ' -SUBMIT IN DUPEICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. APl NUbtERICAL CODE AI D WO KOVE OPE T OffiS ..... UNION OIL COHPASY OF C~IFORNIA 3. ADDR[SS OF OPERAIOR 9. WELL NO. G-8 RD 4. LOCAIION OF WEkL .... 10. FI[LD AND POOL, OR Wlkl)CAT 1 I. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN ttOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISIIING JOBS JUNK IN HOLE AND SIDE-TRACKED IIOLE ..MND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 26 27 28 29 30 12/13/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' 7"L 7396'-11747' 12/14/79 11751! TD 11207' ETD (ret) 9 5/8" C. 7820' 7"L 7396'-11747' 12/15/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' 7"L 7396'-11747' 12/16/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' 7"L 7396'-11747' 12/17/79 11751' TD 11207' ETD (ret) 9 5/8" C. 7820' 7"L.7396'-11747' RIH w/8½" flat-bottom mill & tagged liner top @ 7396'. Pooh. RIH w/6" flat-bottom mill & tagged prod. pkr. @ 10847'. (3' high) - Had slight bobble on weight indicator @ 10550'. Pooh RIH w/seal assembly on D.P. Stabbed into pkr. 5 times but had to work it each time. Test to 1000.psi - OK. Pooh. RIH w/B.O, shoe & pkr. picker. Repair brake water cooling pump. Burn over pkr. @ 10850' & recover. RIH w/7" csg. scraper on 6" mill. RIH to 11500'. ,Circ. w/FIW & Pooh. Rigged up Dresser Atlas & RIH w/6" gauge ring & junk basket to 11150'. Pooh. RIH w/Baker 7" Model "F" pkr. & set @ 10850' DIL. Rigged down Dresser Atlas. RIH w/seal assembly on D.P. & tested pkr. @ 10850' to 500 psi - OK. Pooh. Rigged up to run dual completion assembly. Completed running dual tubing strings & hung off on DCB spool & CIW tubing hanger. Tested prod. pkr. @ 10850' with 500 psi - OK. Rigged up Macco & RIH & set plug in "N" nipple in S.S. @ 10560'. Set dual hydraulic pkr. @ 10522' w/2200 psi. Pulled plug out of nipple and tested pkr. to 500 psi - OK. Pooh w/plug. 14. I hereby certify that the foregoing is true and c~)rrect SIGN ED_. TITLE DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. Form No. 10-404 REV. 3-1:70~ , SUBMIT IN DUPLICATE STATE DF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. 7.1F INDIAN'ALOTTEE OR TRIBE NAME OIL [--] GAS [---] WELL WELL OTHER 2. NAME OF OPERATOR 8.UNIT FARM OR LEASE NAME 3. ADDRESS OF OPERATOR ~ 9.WELL NO. TBUS G-8RD 4. LOCATION OF WELL 10.FIELD AND POOL, OR WILIX~AT 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES 1N 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. 12 13 11/29/79 11/30/79 11750' TD 11623' ETD (cmt) 9 5/8" C. 7820' 7"L.7396'011747' 11750' TD 11285' ETD (sand) 9 5/8" C. 7820' 7" L. 7396'-11747' Completed x-over to W.O. fluid. Tagged pkr. @ 10850'. Pkr. moved down hole to 10866' (Pkr. Not Set). Attempt to engauge pkr. Pooh. No rec. redressed grapple. RIH - couldn't work spear into pkr. Pooh. Left spear in hole. Burned over Ot~_s Pkr. @ 10866'. Pooh. Rec. Pkr. & Spear. Ran 6" bit & 7" csg. scrpro Tagged fill 11587'. Circ. clean & Pooh. Perf'd below H.B. #4 for isolation szq. f/11430' to 11432' w/4 - 1½" HPF. Ran gauge ring and junk basket to 11420'. 14. I hereby certify that the foregoing is true and correct SIGNED TITLE DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form 10-403 R E~I. 1-10~73 Submit '*Intentions" in Triplicate & '*Subsequent Reports" in Duplicate STATE OF ALASKA 01'L 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.) ~' o,- !-~ GAs WELL ~L~.~ WELL OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA P. O. Box 6247 4. LOCATION OF WELL At surface Cond. #45, Leg #2, 1874' N & 1382' W From S.E. Sec. 29, T9N, R13W. S.M. Cor. , 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Rt 99' Above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE ~L-18730 7, IF INDIAN, ALLOTTEE OR TRI s. UN~T, FAR~ OR LEASE NAME Trading Bay Unit ~0. F~ELD AND POOL, OR W~LDC~;';~ McAr thur River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) SEC 33, T9N, R13W, S.M. 12. PERMIT NO. 78-45 3ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF [___..J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) See below PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING 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 all pertinent {letalls, and give pertinent dates, Including estimated date of starting any proposed work. It will be necessary to pull the tUbing, isolate the water entry, clay acid stimulate and recomplete TBUS G-8RD, Grayling Platform as follows: 1. Move rig over Conductor #45, Leg #2, TBUS G-8RD and rig up. 2. Kill well, install BPV's, remove tree, install & test BOPE. 3. Pull and lay down existing Dual 3 1/2" - 2 7/8" Comp. Assy. 4. Retrieve perm. pkr. f/10850' & clean out to ETD w/csg, scraper. 5. Squeeze above & below Hemlock Bench #4 for zone isolation. 6. Acidize Hemlock Bench #4 with clay acid. 7. Run Dual 3 1/2" - 2 7/8" Comp. Assy. 8. Install BPV's, remove BOPE, install & test tree. 9. Place well on Dual "G" & Hemlock Gas Lift production. 16. I hereby ~'ertifJ/that the foregoing Is true and correct District Drilling Supt. 8/23/79 -- F (Tl~e~'pace for State of e use) ' CONDITIONS (~I'~APPROVAL, IF[~I-~ - - ITLE TITLE See Instructions On Reverse Side DATE o,, , - z ?-71 ~efur,,,, Document Transmittal Union Oil Company of Calif' :]ia union DATE SUBMITTED ACCOUNTING MONTH 9/20/78 · o State Div. of Oil & (;~s°M 3001 Porcupine Drive ~ AT Anchorage, AK 99504 A~'.O. BOX 6247 Attention H.W. Kugle] Anchorage, AK 99502 TELEPHONE NO. TRANSMITTING THE FOLLOWING: TBU G-R ~aw~ 1 I ~n~l Tir~g~- 2", 5" Dual Laterolo~[ Sepia & BL 2" 5" ~on io " " 2" FDC " " 5" CN-FD " " Directional ~urv~y Gyroscopic: 1) Radiu:~ of Cu~,vatu]'e 3) Tange:atial A,~erag{~ ~" ~' 1 LEASE ACKNOWLEDGE ~CEIPT BY ;IGNII~G ~,';~ AND ~'i-U~il~ COPY MITTAL. : ... FORM I-2M02 (REV. 11-72) PRINTED IN U.S.A. Form 1(%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.) 1. O,L ~ GAS !--'] WELL""' WELL OTHER 2. NAME OF OPERATOR UNION 0IL C0. OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247~ ANCHORAGE, ALASKA 99502 4. LOCATION OF WELL Atsurface Conductor #45, Leg #2, 1874' N & 1382' W from S.E. corner, Sec. 29 TgN, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT To MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re :~' 50-133-,20085-01 I 'l-'t ::i:;: FAiDNLDAiNgTA3LOLoTTEEORTRiJ~ L~i~ : !~ 7. I I , N .... ... . ; 8. UNIT, FARM OR LEASE NAME TRADING BAY IINIT i c' ~'L~i'~'~ ~'~i TBUS G-8 RD ~ McArthur River Field- "~t~Zn:_ne ii. s~c., T., R., ~., (BOTTO~ MOL~ O,BJ~CT~V~- ~ ~i.~: Sec. 33. TgN: R13W: S.M. 12. PERMIT -NO. 78-45 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING 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 all pertinent ~etalls,'and give pertinent dates, including estimated date of starting any proposed work. The Hemlock Zone and the old well bore was abandoned and the well was redrilled as follows' 1. The 4 1/2" production equipment was pulled & rec. f/ perm pkr. @ 10,762'. 2. A cmt. ret. was set @ 10,684' and the hemlock perfs f/11,380' to 11,790' were~sqz'd. w/ 350 sxs of cmt. e 4-1/2" HPF perf'd in 9 5/8" csg. f/ 7928' to 7930' & sqz'd w/ 200 sxs cmt. thru cmt. ret. set @ 7910'. . A window was cut in 9 5/8" csg. f/7820' to 7885'. A plug of 100 sxs cmt. was equalized on cmt. ret. @ 7910' & polished off to 7826'. 16. I hereby certify that the foregoing is true and correct (This space fors'tate office use) APPAOVED BY CONDITIONS OF APPROVAL, IF ANY= TITLE DRIllING SIIPT.. DATE q/lq/7g DATE See Instructions On Reverse Side For:u P--7 SUBMIT IN ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE '~ E* other ln- ~t ructions on reverse si{tel WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: 01L [] GAS [] DRY F--] Other w ELL W ELL b. TYPE OF COMPLETION: NEW ["-] O%'ERWORK [--]1 DEEP' ~lEN rLCOBACK F~] DIrt*.RESVR. ['-] Other ~'1] WELI, 2, NAME OFOPERATOR UNION OIL C.O. OF CALIFORNIA ADDRESS OF OPERATOR P.(1 ROi× R747_ ANI"HnDAaV /11 AqI~A 0eRtl9 4. :-,O~r{OS--O~-~'rt, b'-(-~e~ort tdcati6n ctdaB~] ahit-i~-a'c6&dance witK '~'y~S'tate requirements)* At suF. aceCond. #45, Leg #2,1874' N &1382'W from S.E. corner, Sec. 29, T9N, R13W. S.M. ~rod. interval rePlorted below ¥8'~ S i 2524 E of NW corner of Sec. 33 T9N, RI3W, S.M. At total depth .. ' 2~. ~IN~= ~co~ P-110 · $IZD -[ TOP (iNiD) j BOTTO~I (5~D) [SACt( S C EM ENT '--'-'-'---~ 28. PER27ORATIONS OP~ TO P~ODU¢-rtO~ (Interval. size and number) 5. API N~CAL CODE 50-1 33-2008~:ql ,9/: gDk ]8730 ~ 8. UNIT,F~ OR L~SE TRADING BAY~ .UNIT 9. W~L NO. ~ TBUS G-8 R~ 'i' 10. FI~ ~D POO~_O~ WI~C'AT t ; , HEMLOCK MC ARTHUR ~tVER-'tG" 11. ~C., T., ~., M.. (~OT~ O~IV~) j ~, Sec. 33, TgN a13H . 12. P:IT NO, 2289' S 2749'E of NW corner of Sec. 33, T9N~ R. 13W,.S.M. 78-45 ,= O.TS SP~DO~ il4. ~.T~ T.D. a~cmm J~. ~*~ co~r susP Oa*B*~r~.7/10/78 7/27/78 8/1 9/7x8 J RTJl6' E~EV.~iONS <DF, ~KB, RT, ~a, ~-rC)°]~7. ~-L~V. CAS:N~HEAD99, above MSL 18, TOTAL DEPTH, N LD & TVD[1O. PLUG, B,A, CK MD & TV,I~. I~ 1VIUL'I/',I.~t"LIg CO1VI~L..I~I'~OW~¥* l;~0~)AR: TOOLS INTERYALS DRILLED BY CABLE TOOLS 11750 MD 9866' TVD/ 11,570 22. PRODUCING INTErVAL(S), OF THIS COMPLETION--TO'P, BOTWOM, NAME (MI) AND TVD)' ~. WAS DIRECTIONAL I SURVEY MADE G-3 10,620' MD 8863' TVD HB#4 11,294 9464' TVD G-4 10,708' MD 8943' TVD HB#4 11~402 9560' TVD . i YES 24, TI'PR ELECTRIC AND OTHER LOGS RUN DLL, BHC-SONIC, FDC-CNL, RFT, CBL-SIGNATURE W/ G.R. i GYRO , .. ~25, ' CASING RECORD (Report all strings setin well) , 20" 1/2" wall / ' I nsa;: I - , t -7.~. I,~--~ I .~aq' i ??" I l?nn 16" -- j I II I 2300 sxs 13 3/8'Ij 61 Id-55 J 3103 I 18./4,, 95/8II 43 1/2"&47 J N-80&J*7820' [12 1 I 3300 sxs *WlNnnu cut i.n. q 5/R"f/7a?n!tc '- =. T~o SCP~EEN (MD) SIZE DEPTH SET (MD) I PACKER SE:' 3 1/2 J10~9241 J 7298' ' J /209I 2 7/8 10.850 29. ACID, Si:OT, Fi~AC~i crRE, CE2~iENT SQUEEZE, ETC. D~-~iFII 1NTE~VAL (MD) I AMOUNt AND I'i!ND OF MATE?.IAL USED 11,264-11,266 ISOZ'D w/ lO0 sx cmt. 9017 [SQZ',D w/ 350 sx cmt. Liner lap JSQZ D w/ 300 sx cmt. i~ 7396' /;_ {:":::,,-,,,, ~:,; :,~,,, G-3 4-.32" HPF 10620' - 10645' G-4 4-1/2" HPF 10668' - 10708' HB#4 4-1/2" HPF 11294' - 11324' & 11332' - 11402' ii 30. PP~ODUCTION DATE FIRST PI~ODUCTZOlXT [ PT~ODUCTION MEi[{OD (Flowh*g,gas lifL, purnping--size and type of pump) ,, I[V/ELLsnu[-in)STATUS (Producing or 8/18/78 j Gas Lift ,:, : ,J.,:: ~.P.,~oduclnq 81~]/78. t 4 1]07/]07 =. J 303 I ,Z~,~ ~: :l I ~zz ~, ~,m~' Ic~s~o P~ssu~E lc~c~ oI~ss~, a.~z~. ' "" 'W4:~.~X~L .' ' Jo~~ an.v~Y-~i (co~.) 100 11040 ,I ; [ 1819 , 1767 I 5 ':':'::':':':'::':t }3.4 --- 31. DISPOSITION OF GAS (~olgj used for joel, vented, etc.) ITEST WITNESSED BY t 32. LIST OF ATTACHMENTS " 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-available records *(See Instructions and Spaces [or Additional Data on Reverse Side) 9Llg/Z~ ..... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the intervol reported in item 30. Submit a separate report (page) on this form, adequately'identified, for each additional interval to be seperately produce,J, show- ing the acktitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this 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 interval to be separately produced. (See inStruction for items 20 and 22 above). .... 3~. SUMMARY OF I~ORMATION TESTS INCLUDIN(; IN'rE~VAL T~TED, P~E~URE DATA ~~OV~I~ OF OIL', GAS. WAT~ AND MUD , ~ NO CORES N0 DRILL STEM TESTS 3~.'~E DATA. A~AC~ ~1~ ~~ ~ ~I~G~, .~O~O~, ':~~..~~ ~.~ t ~ ~~lO 'Stl~'S '0~ -'OtL, ~G~ '~ W~. '1 NO CORES :~ .i ....... . . . . .. ...... , ., . U !'41 O ?,,; O I L C ©. :3 t~' C A L I F b,::: ~,i I A :3YP. O$COP~C SUc?.V~Y tANGE,',~T I AL A,V~'.~A(3E~ ANGkE ':'~L~THC[) OF Ct2?,,PUTAT[ CO~,"~PUTFD FOR SDC %Y F,?q. LiN[)SF;Y AND ASSOCIATES KI::~ !i!'LEV 9 9 FT, 800 · ? 2 899.70 998,60 1652.~3 1 ~ 96, · 02. 2127.23 236 ~, · q 1 2 5 23, :':: ~' . C ~"~'" P'~" I % :~,'! E L E'C T it,'. O N I C ~.~ T E !7 :~, ¢;: : ~t,~ i~'~ ....... ~ . 70'76 111,(~3 ~' I le, 5,(:: F' !34.7q S 150,~(.') 1. :~I · I ~ .5 !86.52 191,2" ~' 227,16 ~" 222,&<'] S 271,93 F 25 ~,.07 c '~20,C:7 ';: 3&C.IO 9 ~77.75 F '~ '0 % . -,21 S 530, i~ q 29 · 76, ,S 5 ? 2 · "7: '~ ~'~5.63 S 633.17 497.:';1 % (.~:t3,6z, [:. ""'~ 9~ S 7':4,~1 502,7('~ S 734, ~? :~f:,12, .. .,< ."54,3a. 20:-.,::,k'z, $ 45 13 246.51 $ 49 296.g6 S 49 54 ~!:51,,42 $ 50 41 26 6 59 11 21 27 LEa I TY O F l 2 · 2 · 500 2.2~ 2,560 a.250 2,777 4.273 3,7~4 2.575 (] ,:! 12 1 · 1.185 2,577 j, 7 ~! 5 ,.) · 0 :)0 5 E C T I O D I STANCE 0 · 0 O ~+6.22 60,97 80,2t 201.~,a 20.5,73 205.69 349.44 466.94 529,52 b91,~!7 774 * 79 833,93 951,83 ici :,;, 31 P,,'~EAS. D-i'~:[FT VF'gTtC~L DEPTH ANGLE OEPTH 3200 36 I!:> 2864,~2 ...... ~,, 2 292 ':~600 qo 30 3179 3700 ~(2 0 3256~62 3157~62 ~.- L, ,~,, 3900 42 45 '3~06,55 3307,55 S57,O(;E 4000 41 0 3451.01 9 9 ~ 7. 5 a200 t, 3 0 3691.0~a $532.06 552,00:.F 1029,4.2 $ taS7':79 !:7 1784,62 5 54 46-19 i i I(:~,98 1166 · 30 12 "~ 1 · 77 i290,2~ I52.9,44 l=~?.~i ia06,51 1 ~' ''~ 29 !562,i~' .~ · ~ ,.. ...... 7 '~ f;: 4 ~ 52, ;h 7 a 7 ~ '~ · ~ 7 S 51 · :.:~,.,', ,F' 16 77 · ~ ..... 171 r, 01 0.591 1,,'750 0 · 790 1 1 0 ,, 500 1 1,;419 2,659 t,979 2,347 3,0al 1,750 9.851 5 t,G21 <; · 7 50 ~:. · i ,3gl 0 · '?93 1,~46 SECTION Oi5t'ANC. E 1126.81 1186,18 1~. 6,30 1306 · 54 t 36 8 · O1 1 ~ 30 · 46 1559,97 1625,52 1690.3~ 1756,61 i~26,2C 1973,45 2 O ~+ 3 · 6 21~, 2156.0q 2227,29 225e,98 2349, ~9 ZN35,2Z 2595,9~ 2657.06 Z7i7,73 277~.29 2~,~36,96 U :: '~, ., ~, ~ , 3 50()r"~ .OOF 179a.37 ,.,~, 2596~3'. F 6 '300 37 () 525_ u · :':. 7 ~'::, t51 · ::; 7 $ 49 · 3 .... (~ [' 18 73 · 57 S 2 ~.~ ::'"'7 · 49 ....... . ,. 3~9, .230 60 $49,00E 1.913,16 S 2533,05 65''~' 37 '3" C .... ~' 03E 1952;99 S 297n ~ ~:. ....................... i9a2-:~1 S 2675. >7b.a aT <* 55A~:,.47 .... , . · ... ......... ,: t., 31 , ~"~ ~'~ "5 73 551, ..~:' 20~'~o 6 2716~61 E 7000 3T '~?, ;~n:~7.26 5708.26 546.C'0E 21":0 ~z ,.. ....... "':'~ "851.29 E '1i00 3~'.~ ~5 5~87,::}0 ?:7'~a,O0 S~5,~;v:: 2192,65 S .:: .... ,.': ,.. ;' ....... -,... .. 5~: , ~ 2893 37 ........................- .- , . .:, ,, ~.. ,.35.52' E , , . ~ .~, ,. ~ ., %.~ ~ . ~,.. ,,, ... .~ . 7~''''~n 475 4~ F2C':':~,')9 Al. 0g,~9 $~.,v{~c ~' ~1,59 q 5"; ~¢'~}~ 3e 45 4~c'? "a (..263,0n SAA, ..... .r. 2~37,/'g S 3122,.;, ,,' .................... .1(: 5 3167. 70'':~ 57 :~:"~ '~2r. 61 / c'~"~' ",, 49 ~ 32<)~,,. · :;z, 21,51 536. .., t.. ?v~4, ...... 80'~'::,. '3~ a:~ A5')~.2~, . 6.509.2~~ .... S32,OOF 25'7~,.~°- ,.., S :242.56. F e~r:;~ ':~ ~, ~7~:,.;.~ a(~56,o4 532,A0~: 26~I,12 S :~3:):.,~ a~Q:; 36 ~'? ~-,914,0t 6~'I ~..,V6 529,r'C:F 2v::6,b'b' c :37:, !4 :~:(;'" ~ 6"~: 797>' 27 <: :2-C; [:' · ....: 3t ::i 7.?:0 79 71Cl,,:.:. · .. ' -. - , .- · ..... 535, ,'~.,~' .... 347. I. C L 0 STANCE 2932.99 $ 53 15 3 [ 2993.7~ S 53 10 29 [' 505fl.ll S .53 5 161 E 31.14.1~ $ 53 0 a7 E 3174.35 S 52 56 12 E :~234,72 $ 52 51 47 C 3295,52 $ 52 t~8 4. E 3~15,36 S 52 4t 28 E 3475,~3 $ 52 38 t~9 5 3536,95 $ 52 33 28 E :55?6,59 $ 52 26 22 C: 3710.32 S 52 17 4~ ~.. 376:~,<:':'~ $ 52 13 39 E :~633,~:9 S 52 9 26 3596,21 S 52 5 18 E 3961,49 S f12 I 22 ~:. 4G22,69 $ ¢'1 57 14 4',')fi2.Z~, 5 51 ~7 59 E ~14i,06 S 51 32 19 E 419~,Gi S ~t 15 lq E ~3-16.33 S 50 41 51 E fl37",15 $ 50 24 42 E '*~27,25 $ 50 7 49 E ~'76.43 S 49 52 15 E /~52'7,~3.. or ~9 40 10 L ~577,31 S 49 3~ 2~ ff DO <::: L E G DEG/iOOFT 0 · 660 0,609 C · 0 (! :) 0,6~6 t 2,338 1.958 0-963 3,9~1 1,602 3,5q0 2,250 [) ,750 1,250 2,767 L} · 750 1 · :3 b 0 1,152 i,388 1 2 $ aC T I Oa a I $ 2899,69 3020,69 3~01,40 3322,02 3381~1 3502,99 ~563,34 3620,g2 3676~97 3736,70 380'0 · 3 3928,36 3989,67 ~110.~0 4171~3F ~232.13 ~ 292 ~ ~ 406 · 7 4~59,5 AL:L CALCULATIONS OEi.?FOi;~,:?:D E~Y I F~, ~,:! E'LECTF:Of:J[C CO?iPUTES; DOG:: L g G SEVER I TY ,: ,o t I 0 0 F T 0,500 0,'? 26 3.041 i.,alO 1.5oo 1.722 0.868 U, 5 17 1,362 ],169 2,134 ti. 5 00 0,o~7 0 · ~. 56 i ~952 <.; '" 9 F,O 0 · 500 $ E C T ! 0 01 $ l A N C E 4662,40 4765,39 4814 · 09 4859,06 4902 · 6ii~ 4986,19 5069 · i 5 5112.13 '~, 155 · 77 52~3.70 ~"2a5.90 ~ 32 6. ~2 5366.25 5~06.27 5~47,93 54~0,.~9 5034.25 5577,65 5621.15 56~4,~3 5708,51 5752.b4 5797.54 TOP F" Z. Of':~E B599 TOP G ZOf'::iF 10116 TOP ?Ef~CF~. tl, 263 TOP (:~ghC~,.45 t t425 TO I !750 8741,90 364~5,41 S 9A37.15 3955.06 $ 9866~37 A163.55 5 5168.21 $ 47 t3 34 E 8509,~9 55~0.87 $ 45 54 88 E 9156,42 5619.53 $ 45 40 52 [', 9277.0t 5645',4(5 S 45 34 0 E ~719,96 S 45 t8 15 E, 9481,66 57f~1,58 $ ~5 5 15 [[ 5817.:.)9 S ~g~, 57 27 [ 9673.07 5265.37 S t, 4 ~6 37 E 9767.37 T o T A t ....C 00 R D t ~q A T ~: S ? 99 299, ~ .~ r. 499 a99,, 400~ 600 599 ~ 500, 1 700 699, 600, 800 7a9, 700, 1()00 999, 900, I I ?~ 1. ] q ,a o I 0 S 0 1203 i!9g. 1100. 1306 1299, 1~00, 7 i 4 t 'I t 399. 13 C'~ 0, t 2 t517 1499. !400, 18 I626 1599, 1500. 27 1739 1699. 1600. lng7 l?g~, 1700. ? I n ,;;, ! 999 · ] 9 (". 0. t 0 . ~ 2365 ?]99. 2!C0. 166 ~ ~, ! ~'~ 2399, :i~ ~ ~..0, ~.',, . ? 579 259'9. 2 500. 27 3119 ?Vgg, 270(~, 32?. :~49'6 :~(309, 30C:'0. 3625 :~ 1,99. ',! CO, 37~. 32c~ ":~2'~r~ 457 41.57 '~59e, '~ !~, 00, 6,20 1.2.42 t6,56 18,64~ 36,03 52.24 72,19 95 · 2.02 252,64 ..,':~ 09,73 374,45 512.07 5~2,7 9 706,3F ., ,79 331 891 · 56 952 !0i5,05 1~}79.88 1292.93 t~3b,2a T 0 T A L, C 0'0 R D I N A T E S 5 0 9 7 5606 59~?.4 6~a7 711:~ 7~]~ 77h7 >~127 &190.. 4190~ 771 ~:~999, a~OO, 5099, 5OHO. 1012 !3199, 5100, 1037 5299, 5200, 1062 5~,g9~ 5400, 11 14 5599, 5500, b69g, 5~ng~ 1164 579g. 5700, 1191 5~i90, 5~00. 1.216 ' .... · =: 900 · l 23 ~:'. :~ 6199, 6100, 1Z~C 6290, 62~0, 1319 6~99, (~4OO, 1374 !:,59q~, 65(:0. 1401 6699, 6600, (>799- 6700, 6~0, 68C'0. 2 ~ i 89 7. $ 6 $ 26 1947,84 26 1997,45 25 2094,53 ;?7 2146.00 Z245.5i 2'? 2346.57 ':~ "' 2 76: 26~2,71 271:7.34 277'~. 1594.38 i675,31 1.737,47 t 796,69 I857,66 1916,27 1980,97 2t03,12 216 3 · 9 .~ 2.223,65 2'342,B0 2515,z~4. 2572,93 2630,92 27q5,89 28{;3 · 50 2857.~g 2908,7a 2 ~; 61 · 9 ~ 3(.)i~4,20 3197.15 3326.Jl '~a3 9 ' ., a~.57 729g. 72C;0, 1557 17 ~:~ ~7~ 7~o0, 73:~n ..... , 1~7~:' ':)209 7509. 7500, 1610 I ..... . 162::: I 5 . ,,~ 94~6 779g, 7700, 1 ~;. ~ 7 C54~ 7~99, 7~00. 1~9 t2 o771 q09~, ;~ 000, 1672 1i 9<~q3 ~5299, ~200, I69a 1t 044<) ~6q9, ~6()0, 1,7~t 0550 ~799 · ~700~ t 75t 0659 F~399, ~,f~ OO, 1760 9770 j999, 8000, t77t Ii 0(~82 9099, 9000, 1703 i2 OOO~* 9199, ClOO. 1795 12 t107 9299, OPO0, 18:}S 1:~ 1466 9599, ~: 5 C;-O, 1847 13 t~59 9699., <5~ 6()0, t B60 ?,.63 · 5'3 3 ~* ':"' 7 · 4. 5 3626.9t 3652.75 3~'76.53 374 2 · 2 8 3766.28 3791~23 3544,12 5691,65 3914,59 3937.7,* 3982,2<:; ~003.63 g047,77 4070,27 V F :~ T I C A L :S U !.: c. P T H .5 E' ~ 1916, 4222, ~123, 501.1, 5807, 5708 6599~ 6500. 7~21, 7322, 9204, 9t05, 9~. 03 $ 1353,63 1368.51 S 1872,12 25~5. ~'~8 S 3242,56 305b~79 $ 3538~27 3a, 6~,15 5 376,'7,7a 3~44.37 $ 3963.37 V"-F'TiCA L UNION OiL COMPANY OF CALIFORNIA SCALE t"-- iO00' GRAYLING G-8 RD, TANGENTIAL AV2ikAGE G YF'~OSCOPt C SURVEY \ . .. 4800% X. 6000 . A~._ DEPTHS SHOWN iai'=._ TVD J ~uO0% '/' ~00 ~ 800~. 6z~O0 -~ 88,00'~ 9200-¥ 9600-~, TVT_,= G,SGG' TMD = ',i ,7S0' UNION OIL COMPANY OF CA~_iFORNIA SCALE I"= iO00' GRAYL',NG G-$ RD. TANGENTIAL AVERAGe' GYROSCOPIC SURVEY ;200 ............. 2400 . 2,0 oo ....... ;00 4.000 ALL DEPTHS SHOWN ARE TVD A/~GL & S E: V E: fi: t T Y o ,~. G t i :0 C F T C k x-: -><' U q E S S T .ah:; C :::: ;:~ ~ O t E.': ..... IOOF' T 1,750 i.174 (::::, 5 E: 0 t.,b36 1.419 2 .'b 59 1 · 97 q Z ,347 1.750 2 · :3 :: 0 3 · :3 2 (.: 0 · 9 e 7 ::::',. · 2 ~'' o T ant E O 6 G / i t:: 0 F T .... ,~ ~ < 3Oa 1 ,, 84 3202 · 1 2 3383, 3503 · 65 3564,5C S624, 3679,37 3 '79& , 77 39 9", 5 5 4 1 15,9:5 a3t, Z.72 t, 515.6.7 ,b tt ...... $~C T i /'% ";' J '3 .z, ": 44,6 '? 6 r., 9 :, (,: :~, , I 11117 t 173 ":5~ .. .. ' ............. ........ ..... HORIZONTAL V.[EW UNION OIL COMPANY OF CALIFORNIA .... SCALE I"=1000' ......................................................... GRAYLING G.~.8 RD ..................................... .................... TANGENTIAL METHOD .... GYROSCOPIC SURVEY · . · .... .... 4oo57,soo~ ....._ ..... .. ........ ~;TiT".i"'.;.FiL','~T. ZS'2-.'T"':-'i~'Zi'i~.-,"Z ~'"_,-.SZ.T~"~F'._~;iYLiTi~'"'~i.~F.'."i".~''I'~I ....... .'.- T ;i ..... i ..... .i ..... ii i'. ,' ._'.'~' 120~ ~,~_..,,.600 ............. ; .......... ' ................... ! .......... : - , ~'~-.,2000 ........................ : :: : '' 1 ' ' J ' - ,.' ._ -...',~~oo-'-' ':-.-.-::.- ...... :.:':'_:'_::.-:.~.'::.':.:::_::v.:" ::.:'.:'"": :.:.'.l "~[' 'rv~- ""-" I _: ~' ' ." i .... '~'. ;'i '. ¢>~,."...~ ~ 4~..0.o i; .'~"i''~.'' Y" .q. _'-}'~...i'il 5'~' '_.'. ..... "' 'i' '":i':-'-'.:-.:"_-"' ""F'-',:-:-?-~'°~i':' .:'-.~,ooo --.~ .... , ..................... . .... ' · ' ' ' '- ' ..~"~ : '-''- ,' ~9 ..... .--' ·" - · ~! · ' ' " oo°: i":"-:'""':-" ' ' ..... '. ' : 400 [ ......... ...... ..... i-' i. i .......... ~1~ , - : ' ~ TVD= 9~857' . .............. · : . ........ ! _ ' . ............................................. , ................... - ..... . . _ , . ................... . .......... ..................... ,. ............................. -- . ................................ ?* -. ......... , .......... ........................ ........ . _ . ~ ....' ; . · ............... ,.,.o,:, -- . ............................... VERTICAL SECTION l; . I! UNION OIL COMPANY OF CALIFORNIA ,soot · SCALE I"=t000' - t', GRAYLING G-8 RD. i'-: ...................................... - ....... TANGENTIAL METHOD ........... 1200 -- \ GYROSCOPIC SURVEY _ . . 2800'~ · '.-~ 4000% ALL DEPTHS SHOWN! ARE TVD , [> .~' 'ri ' '"' .. =: .... C L (i; ~' U ,q 7. a/+ S 6i,70 ./ ].~ r,;q Z' ~,, :~ ~ ~:, ..~.~ i3,C,P6 S ~.5 'J63.~:0 S z+6 2C? i~' 296086 S ~5]..32' S 50 470.:.ffL: S 5 53,-~.ez~. S 52 7:' ,1 5 " 'f~:" ,63 S ..... -. ~,, )' ,: :':' 0 O !,'~; O · C 00 9 S & E 2 ~ 25 l 26 6 El 2,5 ,t & 5 7 55 ~-" , · 2 D 0 e ~ .... ~.'~,, 8, r: 2.7~: :~ 54 23 E 3.761 41 51. E 26 5& E 6 .43 E 2,533 5 9 38 ~ 1 · Z 0 36 i6 E L'/ 2t :' 59 C E ~:',G2': ~ I 5 [::: 0,5'..~. 27 22 : 1,:':'2 2? 29' ~' C'.5:2~ SECT OIST~ ,,, 60 ,, ]. 0 :: 201 529 7 ~" 2.; i ';' '1 :.'< LJ [::> D c: 1,7 ::' ('i 1 t': l · 0 7 2 ! ':~ (: 7 :-. :i · "':,.... C: 0 l '~- ~' :: r' · z. (.',, 5,,"' "', :,.~i 4 5 :: E::: 2 · ! ? 5 l G 2 ] ,, 3 0 '~ l ' .... 0 ';~' .,. 2, ....,c:, ,, .' l. 9 7 4 2, Y z, 6 ~ 1 (.) 6 C * 'q r: ,::: 2: F- :, 'i · .. ~.... x :: 2. :3 · 7 :) ,.} F' f:' :, c, ~ .?f~5.. 2'-~12, 2 · ] 27 253<!, '?. {;: 5 f :'" ~ .., · S~"9 27-'~ . . . ", :' '7. :: 2 :: :'::, ] 5329,27 5727 ~ 7 613i 62nS.., , 03 636!. 6598.70 {,677, f p-- 7/., {, 994.7 51~'' .523 {'), ? 7 53;59 ~ 21 554.9_ ~ 2 5 62 ~ ~ 79 57 g 7 · 4 :,09 · 24 5951 . -;~, 32... , 6421 · 04 (-656.36 6734.76 6 r.,_ i A ~/' 6 ~1:95.7 7 6975, ~ 27 k}~:' ~ - 7 ] C ~ ~ C DR IF'T D I r:::: ~! C 849: $._fi o Sz!.9. 549. S 48 · 5':bF * S43 · ~ 32 · S27 , S 2 9 · C,: 0- ,-~ ,~ [.' <.'. '11.', ~2 ,-, a L: 00 E 00 -' ,.90~' 00E 0 ,n,., '" ~ [1'2 C: (; P2:h C' 0 :'7." O 0 E' 0 0" ,-... ~,.- "",, '3' [' v ,-. ~: --. 3:,)[ ].~7S,..,, .: . , ....... 3.9!2,97 S 2532.82 ] e,, ..n 2,79 $ 2..,:: 7 {:, E' 3 1972,22 S 262A.79 ;" 2 ;9 ~ t..~ q 27~5,3o ..... "' ': 7 4 2i50, 1', q 2~:,{::~r"q 219 ~"' ......... 2 ~ r)'8. ' 239'-~0'-~ q 3{:7%,2:': 24:~'7,45 S 3222.,4C :. 2478.~5 S 3167. {.d, 2526~i9 S }207.13 2975.36 S 7;247,212 262~01 S S27-'.!2 [.. 26:C'.~'' S 33(:::,~ 275A.01 c. S3z.-" ":' 27 f ~., ~:,/.,,.... ,. ,,c ?, L36% , 7'"',~ ?-,. 2~'~ g& ~ :3-~ S :. z-.23.:':' '~ L: ]./. ,. 7:~- 3:::.'-',:'z. C h CI ~: !f i'R c q DI CT "'~" ~. i-,, ,~ C i'! A N (',':' L ii': D t"; c ,.2 0 48 E 55 13 E 44 3,1 E z~, 1 ?' 9 E 38 50 E' 33 29 [: r:6 2q 21 ],5 E 17 4 5 F! 15 40 E o 27 5 ]. <% : 1 23 57 15 E 4 8 0 E. 32 20 E: 15 2]. E 4 ! b 2, 24 z:3 ~:. 7 5(,: E ,:.0 I]. 3'3 2:<: S' ,,. 2:] x D E (!, I l 00 F T 0 :: 0 '0 C:', 2 50 "' /i b. ~"~ 3. ,. 025 2 ~ 142 ].. 34! 3 · "' -,71 i.536 3,500 2.250 4 · i 0 't 2 ~ '3'~, '~ 5 1..} ,30 i · 299 3.. 7 i; C; 2.1,5A ~' ,597 D ! S ], 302 :,!4! 1526,2. 3 q': ';' c 3 D & ,< 3 62: 'J. } 7 ? '. 4351 4122 ~.2S~ 42 ? ': 44 {: ': 4.5 ! :L 45(: 4L,] ' /, $ A L L oaOn 31 30 7~:o0,7~ , ," , , q f{ · ;400 2:', a5 960.0 2:45 7944, 53 °nO3 25 ~r., ~, .,vuO 2o 4p 8304.~4: ~ 02 C..,..,2 7 ¢' 8 z; o 2 · 7 ~: ] ~ L, ~ ~ ...... ,.;-,.v,,, 25 0 36~2~P? i0n~'n "4 ~,r':, n7 -~ ~,,-, k ,.' ]' ",~0 2-1 15 91!4.7! : ...~0~ 27 45 aE~''~.. ~.z)~x.i, !i100 27 30 11200 2'1 30 9~0.71 ]]4Ca 27 33 95t;7.9t 2.!6C.{J 28 4.5 7406,7]. S33~00E 769].. ~ 75 532000E 7575,34 SS1,COE 76'', 7935,69 525.C. 0E {)025~95 ~::$ ! ]. 5, eS S28,OOE' 8205.42 8294~f:2 529.00E ~} 3 E; .3., 72 532 ~:745,27 53 t, .......... 8925,9'1. c2n ~,m .... 9015,.7~ 525,00C 9!Ozr.41 524,0()E 9~93.C, 1 q2F~ ,-/i · " .., ~. i. ~ l','/O. '>'! S-' ,.,. 9z:5[:. 91 52 6, ~-, '~ 54. '/./.. I q 2 ~-, ,., C: [:' c: 655,/: "' S 25 ~' (:;-' ,' , .k' .. '10TAL C(::~, 'u ~,, i') I N A ]' L 5 C L 0 S U R E S D t S T/',. :'...; C ::: A N (:', L :: D ;:"1 S ,.,,:.,>7 5 3506~:,., E 3 ! 46,9:5 .S S 5. 94 ~ ~?. '3 5189,57 S .:<.,~..:.,:.. 3229,[:3 S 3644,4}.: E:: 326::,4"~.. ,.,<: 36':>o',]4 :.: 3 * z, ~'. :~:: 04 ,<:, 3705,36 F .. , ::: ~,.. K. ' ~ ..... ~.a ? 4:::::7a... ,_ . ,,,.< ' 7z:5 <'72 4727,17 S 48 47'77~67 S 48 4~;.!25,4.2 S 4S ~:9'i2,20 S 4.: 4993,91 S 47 5034,14 S 4,7 3901,75 ~ 5:558,~c',~ : L6 El. .,' il: ~, 5922.,'/0, :l 5404,64 S 66 3o:z,r:....~. : 5~2)::','~:-- ~ .. S a. 5. 40Cl.&'4 k 55-1~:.Z7 S 45 z:,Zz:(',,(:a. . E: s":"x.L:;.. ,':"'6 S a, 5, , 5'/ 7 3 S z. z.:!?:::,::7 ::'. 5:.6/:-,'79 S 4" ~ [..A "IOP F ZO!',!E 8599 i r') ,'h I-' ,. :,~ ~- '.',.:~ TOP O (,')IL. 10z~87 T"P..., , 'fOP BENCH2 !1098 TOP 1' 0 P l 0 F' Th' i ] 750 70 7 ? 87z~.t 92 54, 92~ 0 ,c:, 4 36 9580 9702 9 '772 :2 ,.,. 7 6 ~ ~ ?756.75 2-? 9 [. ,,-~ 8" 0 ~ .. i 204. i :O 7 14!i c:~ V 1 9 7 c~ 2619 27& 5' ,. . ~., ~.: ~ ~:., 199 ,, 10 C 0 C ] 799~ 200 0 0 3,,5G S 3 ::/.': 9 ~ 300 ,.., " 0 6,~;5 '" S '" ~ 0 A 499 · 400 0 59~ ':, · ,. C 0 0 0 i 699 ,, o ,..~ 0 O 1 c/, 79?, 70r:,, 0 0 p. c} 9 ~ c'." .... 979~ 900 i (,) 4.0,5!) S 1 0 9 e, ] C) 0 C, 2 i ~, 99 · 1 ': ('1:0 z~, 2 6 2 ,, ? ] c. - ,.,0 7 ! 39 ? ,, 1% 00 ~ ]. 'n .. ........ . ...... . ...... ':' 149 o ~ t40n ] ~, ., .. i .5 ? 9, t 50 C, 27 · , ,,.. l F~ ? D, I a 0 C) 7 ? 2 ,I 24 7. {:: .{-}, S 1, c!99~,., lq'nO.. ,-. 106 27 2':,1.].2" ,.c 209© C'O ~. 2 O 137 :51 3:37,2'? S 2 ~ ~C. 2 ~00 160 2 22?9, 220n,.~ !95, 23o,- ;'~, 2300 22"' 25 .. ~,' ,,., ,. 2<.~:, 2..4."0~.,, £a5, 25'~''', 2:; .~ 27] 2~'e~ ?' O0 2cA "' ...... , ,=: z. :., :~ q-L= 34 $ ;.., , ,,_. o, .. 27,qc :.' ;., 2700 320 2z~ ~,"~:- q'b c, ' . 2 :':t o c; "'" . . .., ~ JO0 _.'~Azi. Z'--. ~": 7:2, . .. 2 e 9'-:. 2c0''' '~ '}' '~ .. .,. ',. ~ ~ 3 :t c.....'-:..3 .~ C'"u A :-.'.' (': : 2 :.',. :;, 3 "' (~ 2 L :;" 3 :' i. [.-. '/~, ,:: } $ :23 ?.; ~: ,~ ':.:.. ',.. r'.. (1,, -"-- i' '4 ,"~ :' {':. :~ ,, ,..~.' % ':' 3" q {7, 5 ' i: :3 P }: :}. '";: '-' '" ' ., v' ?., r:. F' t'. 350 ':' :.i !~ ::" % 2,0 8,27 1]., 2r- 14 ~ 72 ]3,64 2 4 ~ 76 72.ti ]. 24,54 ! 5 c:: 201 , 7 252~22 3 7 4.5 443. 5tl .9 79~ . 642 · 5 706,47 53!,82 951,54 ].,..'_"-'3 5 ~ 2:a. i {:. ,{~ '.1.). (: 0 i ]. A 7, :Y 12i ~' i 29,2. :':i ~'. .: ~ 3 & ~ ~};- ./' V~.r'< 'i; (J 1-. L C t: !'~ :'-:: i'. C T [ Cji ;.< 'i C '[/-, L 4 F', q 9 47!7 a971 50?7 5225 53' 53 5733 6!11 673~ 6~63 6~90 71~5 7237 7~60 74~ 8 7619 7768 797:~ 8 O00 o256 8352 37? 409 4. 29 437 509 v.~9 619 629 6~9 o 79 709 37 (' :) 6 z:. 3 4 0 00 7 44 4!00 772 4.200 -.~ 3 C 0 82 E. 4500 85 () 46 :"0 ~ '" V 4700 934 4800 95:9 4 r"O0~ 9S6 58~''n 5100 103 5200 I062 5300 I08~ 5400 ~ ~ 14 5¢:00,; i ],aO, 5600 1194 57O0 1!91 ~o0~ ~21~; 5900 !2S8 6r'('O 126r: 6100 ]289 6200 t 32: () 5300 1349 6400 Z ~ 76 6500 3. z~.a 1 .... 6600 fC, u 5oC)0 1 3 g ]. ~' 7 ',:' 6 5 47 i23:~ 0": ' r",~ i/,,o~ ...... 28 ]25~;.05 2¢, 130¢,. ;~ ~'1: 2 ?. ] 35 ',:; · 96 2 7 165 !, 45 ~ :. ..... 1697,9~ " f': : 1 '~" 5 7 2. ~:' %:" :"::: ::' 'P:~" : ," .... ~7,9 26 1947,89 26 1997~ 2.: 26 2046,5 7 24 2095,88 27 2143,92 2r' 21q5,7t 22 2.245,2i 22 2292, ~'. 2c 23a6~L3 3i 2403.15 29 2457~37 25 251.1~19 S 27 2642 ~ 59 29 2713,57 ? (: 2:77 't, ] 3 ?, c 28 (': '/~ 05 150 ;;, 73 ! 737,4 z; lg57,90 191E, ~ 23 I c:, 8 (') ~ 6 3 20 4, ?; ~ 5 7 2223.:-<~ 2283~22 25z~2,67 2401,21 2 5 i 5 · 4 7 2~J72 2630,51 2688,35 274~ 302!,31 3084,3t 3144 ,, 3 4 324,2~ 22 3354,56 D::-, I r-i 8 9 '? 4 9'325 943 7 ' 60 9771 9982 9994 10106 10218 i 033 O 10440 10530 ~., 10770 1O882 11108 11221 11~46 ~1560 11674 719'9, 729-~ 7499, 75c9, ., 7699 .. 7799. '1~ 9'?', 8~99~ 8~99~ 8599~ 8699~ 8899~ 8999, 909° 9199~ 9299~ 9399, 9~9~ ~599~ 9699~ 9799, 7100 7200 7300 7400 7500 7~.00 7700 7900 8000 B 1 O0 8200 8300 8400 850O 8600 8 '[ 00 88O0 8900 9000 9100 9200 9300 94OO 9500 9600 9700 1593 i626 ]. 638 1' 1.67~ J. 6E3 1707 t71~ 1731 17~1 1751 1751 1771 1783 1796 1809 1821 18~4 t 847 !860 1874 i7 17 15 12 11 1t i1 10 10 12 13 13 12 13 13 2e47, J 4 2996~19 :~ u. 9 · 021 3199,58 3244,07 32~'~c: i6 3332.40 3417,74. 34, 61. ~ d 0 z~49,!2 ;,,,, 7S 370'9~ 29 3'749 · 83 3794,52 3841 ~ 3889, 3936,75 3954,1q~. 4031,38 4079~ 50 u~.. 2'3 3530.51 ~':: 3597,a9 · 3626~5'3 E 3652.70 9676.20 '"~ q7.96 3'/4t .c:,~,. .::, E 3705.99 E 3790.94 ::' 3816,c'° E 3S44~ 30 386 ~:,, 39 3~9~, 30 39~.4~ 32 E 3937,37 3950~31 39~2.03 Eli 4025,50 E 4~47~ 27 E 4069.89 E 4093,!9 4116~15 E 1000 998 2000 19'_1.6 ~ 000 2702 4000 5000 422]. 6000 5010 7000 5806 80OO 659~ 9000 7420 10000 830~. !,1~"00 c~ ~ ~S 3381~ 4911, 5707, 64.99 ~ 7321, ""~ S C (.)P ('~,Ym ,.: i C S,L.iT~ FElt_I- (')F :"i[.:ASU,-~::t;: DF!,-T~'~ TOTAL COO" ~.: r.~ 1 ~',~,,T E S 40,49 6 24.7i E 255.00 S 3!9.59 E 596.03 S 947,93 S 1353,52 E !368,33 S 1&71.91 1754,64 S 2349 2t50.14 S 2S08,00 E 3058.44 S 3537~90 3463 , 77 9:'1 S ~ o 82, .... HORIZONTAL. VIEW UNION OIL COMPANY OF CALIFORNIA .... SCALE i"" iO00 GRAYLING G-8 RD. RADIUS OF CURVATURE .... GYROSCOPIC SURVEY _ '~,.~0 O0 . _ O0 I ALL DEPTHS. SH,OWNI ...................................................... ARE TVD. J 92.0O · 9600 TVD= 9,866' TMD = I1,750' ____._.._VFR'FIO. AI SECTION UNION OIL COMPANY OF. CALIFORNIA GRAYLING SCALE I"=G_8RsIO00' - GYROSCOPIC-SURVEY ........................ ¢ ....... [;otto No. P~ 4 REV. 3-1-70 SUBMIT IN DUPLICATE STAT E O F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, Alaska 99502 4. LOCATION OF WELL Conductor #45, Leg 2' 1874'N & 1382'W from the SE corner. Section 29' T9N, R13W, S.M. 5. APl NUMERICAL CODE 50-I 33-20085 6. LEASE DESIGNATION AND ADL-18730 7. IF INDIAN-A[OTT~B OR ?RII Trading Bay Unit TBUS G-8 (32-33)j McArthur River qi._ 1L sEc. t. r. m. mottom OBJECTIVE) Section 33' T9N, 12. PERMIT NO. 68-10 31 32 33 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 CItANGES IN HOLE CONDITIONS. 8/1/78 ll,750'TD Pooh and LD sqz. tool. RIH w/ 8 1/2" bit & 9 5/8" csg ll,658'ETD scraper to 7000' and WOC. Tagged cmt at 7,353'. Drld (plug catcher) firm cmt to top~of 7" liner at 7396'. Circ o~t. Pooh. 13 3/8" csg Ran Baker stimulating valve and set retr. sqz. pkr at 3103' 9 5/8" 7364'. Opened too for 1 1/2 hrs. Slight blow - dead in window 7820'- 3 min. Opened bypass. Rev. out 8 cu.ft, of rathole fluid. 7885' 7" liner Test was dry. Pooh. RIH w/ 6" bit 3 - 4 3/4" drill 7396'-11,747' collars, and 7" csg scraper. Tagged cmt at 7396' Drld hard cmt from 7396' to 7695', stringers from 7695; to 7835'. Ran to 8979'. Drld stringers to 9030'. 8/2/78 ll,750'TD Ran to 11,340'. Drld cmt from 11,340'-11,623'. Circ ll,623'ETD cmt btms up. Changed mud to FIW and pooh. RU DA. Ran CBL 13 3/8" csg Signature logs 11,623'-7800". RU scientific eye and 3103' 9 5/8" ran gyro. window 7820'- 7885' 7" liner 7396'-11,747' 8/3/78 11,750'TD ll ,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" Ran gyro survey. Perf 2-HPF from 11,264' to 11,266'. Ran gauge ring & junk basket to 11,500. Set Baker cmt ret on W.L. @11,230'. RIH w/ 3 1/2" stinger on 5" DP & stab. into ret @11,230'. Attempted to test annulus above ret., took fluid. Sqz. perfs below ret. w/ 100 sx C1 "G" cmt window 7820'- w/ .75% D-31, .5% D-19 & .1% D.-6. (Broke down perfs w/ 7885' 7" liner 3500 psi, initial rate 8 CF/min @3000 psi'. Final rate 7396'-11,747 5000 psi @2 CF/min. CIP @17'35 hrs 8/3/78. RIH w/ 7" sqz. tool on 5" DP & set @7446'. Tested annulus above tool to 2900 psi - o.k. 14. I hereby certify that the fo. iggoing is,~e and correct s Pk, is~.~a~& q~!i~~l~&~r~.~%. ~,,-/ ..... Dis* n~ 9/15/78 ' ~I"NE'~ ~ .~'~ .... ~ ....~_~3~_~,.~ .,..e ..... g. Supt. DATE ~r,~?~':~ Col lander /~-~' NOTE-Report on this form is required for each calendar month, regardle~ of the status of operations, and mu~ be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unl~ otherwise directS. 34 35 36 37 38 39 8/4/78 8/5/78 8/6/78 8/7/78 8/8/78 8/9/78 ll,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747' ll,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747' ll,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747' ll,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747' ll,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747' ll,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747' Located & Squeezed hole @9b-~./' in 7" liner w/ 200 sx C1 "G" cmt w/ ,75% D-31, ,5% D-19' & .1% D-6 (initial rate 4 CF/min @3500 psi, final press. 5000 psi). CIP @06:35 hrs 8/4/78. Pooh w/ sqz tool. RIH w/ 6" bit & 7" scraper. CO hard cmt from 8860' to 9025'. Press. tested hole in 7" @9017' w/ 3000 psi - no test. Pooh. RIH w/ Baker sqz tools & set @8788'. Squeezed hole in 7" @9017' w/ 150 sx C1 "G" w/ .75% D-31, .5% D-19 & .1% D-6 (final press 3500 psi). CIP @05:00 hrs 8/5/78. Pooh w/ sqz. tools. RIH w/ 6" bit & CO cmt from 8854' to 9055'. Pooh. RIH w/ Baker test tools & set same @8778'. Put llO0 psi gas cushion on DP. Opened test valve & bled off gas to dry test hole in &' @9017'. Had light blow for 10 min., dead remainder of 1/2 hr. test. Press. tested hole @3500 psi for 30 min - o.k. Pooh w/ test tools. RIH & set Baker Model FB-1 perm. pkr on W.L. @10,475' (DIL meas). Completed running 3 1/2" tbg. Landed in C.I.W .' D.C.B. spool w/ M.S. @10,558', "X" @10,527', Loc. Sub @10,484', "XA" @10,451' & B.V. @319'. Removed BOPE. Installed & tested to 5000 psi C.I.W. single 4 1/2" tree. Vamped flow & gas lift lines. Commenced lifting FIW from annulus at 2100 hrs 8/7/78. Completed lifting annulus dry to 10,414'. RU D.A.W.L. & perf 4 - .32" HPF from 10,708' to 10,668' w/ well on gas lift. Commenced production test @22:00 hrs 8/8/78. Cont. Prod. test until lO:O0 hrs 8/9/78. R.U.D.A. W.L. & Perfed 4 - .32" HPF from 10,645' to 10,620' ("G-3 Sand"). Resumed Prod. test 14-00 hrs 8/9/78. S.I. @20:00 hrs 8/9/78 for press survey. R.I.H. w/ myers survey tools. 39 8/9/78 40 8/10/78 41 8/11/78 42 8/12/78 43 8/1 3/78 44 8/14/78 ll ,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" wi ndow 7820'- 7885' 7" liner 7396'-11,747 11,750' TD ll ,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747 11,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747 11,750'TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747 11,750' TD ll ,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7" liner 7396'-11,747 11,750' TD ll,230'ETD (cmt ret) 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7"liner 7396'-11,747 Cont. Prod. test until 10:00 hrs 8/9/78. R.U.D.A. W.L. & Perfed 4 - .32" HPF from 10,645' to 10,620' ("G-3 Sand"). Resumed Prod. test 14:00 hrs 8/9/78. S.I. @20:00 hrs 8/9/78 for press survey. R.I.H. w/ myers survey tools. Ran press survey. Spotted 25 BBL Safe-seal pill across perfs. Filled annulus w/ FIW. Installed BPV. Removed tree, installed & tested BOPE. Spot Dril-S pill across perfs. Pooh w/ 3 1/2" tbg. R.I.H. w/ pkr picker & rec 7" perm pkr @10,475'. RIH w/ 6" bit & drlg out cmt. ret. @11,230' & cmt. to ll,310'. R.I. to 11,623' & spot Dril-S pill from 11,623' to 10,300'. Pooh. R.U.D.A.W.L. & perforated HB #4 from 11,332' to 11,402' & from 11,294' to 11,324' w/ 4- 1/2" HPF using 4" O.D. csg. guns. Reperforated "G-4" sand from 10,668' to 10,708' w/ 4- 1/2" HPF using 4" O.D. csg guns. Run gauge ring to 11,000' Set Otis perm pkr @ 10,850'. Installed & tested dual ~bg rams. Continued running dual 3 1/2" x 2 7/8" comp. assy. Stabbed into Otis perm pkr @10,850' w/ L.S. & tested to 1000 psi - o.k. Spaced out & landed tbg w/ L.S.M.S. @10,924'. 45- 8/15/78 46 8/16/78 47 8/17/78 48 8/18/78 49 8/19/78 ll,750'TD Pulled ball valve dummy. Ran blankin9 plu9 to "XN" nipple ll,623'ETD @7298'. Couldn't test tbg. (Circ @ 8CF/min & 100 psi). Pooh (cmt ret) w/ plug. RIH w/ shifting tool & checked "XA" - it was closed. 13 3/8" csg RIH w/ blanking tool to test above "XA". Couldn't seat tool 3103' 9 5/8" in "XA". Pooh. RIH w/ tbg BP, couldn't run in past 1st G.L.M. window 7820'- Pooh. RIH to retrieve bottom G.L.V. 7885' 7" liner 7396'-11,747' ll,750'TD Changed out G.L.V. #7 on S.S. RIH w/ W.L. & set plug in "XN" ll,623'ETD @7298' & attempted to test S.S. - no luck. Pooh. RIH w/ plug 13 3/8" csg & set in "XA" @7217' & tested S.S. above "XA" to 1000 psi - o.k. ~/3103' 9 5/8" Pooh. RIH w/ tbg plug & set in S.S. @7272', 13' below top of window 7820'- Otis triple pkr @7259' & attempted to test S.S. - no luck. 7885' 7"liner Released from tbg plug & pooh. Unlanded tbg & added a 3' pup 7396'-11,747' to S.S. Relanded tbg & attempted to test S.S. - no luck. Unlanded S.S. & pull S.S. up 20'. (Note: S.S. was free of triple pkr as in the 20' P.U. It came free w/o any indication of shearing out of pkr, which requires 5OM# over tbg wt.) ll,750'TD P.U. on S.S. and added an additional 7.35' of pups (ll.15' ll,623'ETD total). Lowered S.S. & stabbed into triple pkr @7259'. Landed 13 3/8" csg S.S. w/ 15,000 lbs from S.S. on pkr. Press. up on S.S. & set 3103' 9 5/8" pkr - tbg tested o.k. Recovered tbg plug from 7272'. Tested window 7820'- pkr @500 psi - o.k. Removed ball valve dummy from L.S. 7885' 7"liner Installed B.P.V. Removed BOPE. Installed & tested C.I.W. 7396'-11,747' dual tree @ 5000 psi. ll,750'TD ll,623'ETD 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7"liner 7396'-11,747' Installed & tested flowlines. Gas lifted FIW from annuluso Put well on prod. test. G-8L 8/18/78 1368 BPD .5% Cut G-8S 8/18/78 288 BPD 28.0% Cut ll ,750'TD ll ,623'ETD 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7"liner 7396'-11,747' Released rig from G-8RD @24:00 hrs 8/19/78. Form 10-403 REV. 1-10-73 Submit*'lntentlons" 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.) ?.. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR P. 0. Box 6247, Anchorage, AK 99502 4.LOCATION OF WELL At,urface Grayling Platform Conductor #45, Leg #2 1874'N & 1382'W from SE corner, Sec. 29, T9N, R13W,S.M. 13. ELEVATIONS (Show whether DF, RT, GR, et~) 99'RT to MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 50-1 6. LEASE DESIGNATION AND SERIAL NO. ADL 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq Bay Unii; 9. WELL NO. TBUS G-8RD 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, R13W, S.M. 12. PERMIT NO. 78-45 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURETREATMEN~: ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Othar) (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. The originally proposed kick'off point for TBUS G-8RD was at +8670' to 8730'. It is now proposed to change the kick off point to +8040' to 810~'. This change will minimize dogleg severities and still allow reachTng the desired bottom hole objective. ~ - - d]-m R. Ca I I ~nder Dist. Drl9. Supt. DATE .6/22/7R (This s~ce for State office use) CONDITIONS oF Ai;p~OvAL: IF ANY: /~ &/ PETROLEUM ENGINEER See Instructions On Reverse Side DATE SUNE 26 ? 197 8 Jun~ 9, 1978 Trading ,Bay Unit G-SRD (42-33) Union Oil C~any of California Permit ~. 78-45 District Land ~m~ger Union Oil ~y of California P. O. Box 6247 ~chorage, Alaska 99502 Enclosed is th~ auproved applicatic~ for pexmit %o drill the above referenced w~lI at a location in Sece~ 33, Township 9N, Range 13W, t~ll samples, core chips, and a m~d log are mt required. A direct/~ Many rivers in Alaska and their dra/nage s~ hav~ been classified as i~ for the spawning or mi'..c~ration of anadzcmous f~sh. Operat/cns in these areas are subject %o AS 16.50.870 and the regulations ~Igated operations you may be oc~~ by the Hab--ltat Coord/natc='s office, De~t of Fish and Game. Pollution of any waters of the State is profited by AS 46, Chapter 03, Article 7 and the regulations promulgated thereu~zler ~itle 18, Alaska Administrati~ Code, Chapter 70) a~d by the Federal water Pollutio~. c~n~ by a representative of the Depart~m~t of ~tal Oa~rva~. Pursuant to AS 38.40, ~ Hire Under State Leases, t~ A]mska Department of Labor is being notified of the issuance of this ~t to drill. notified so that a z~presen~mtive of th~ Divisiom may be uresent to witmess testing of blowout preventer ~t be~ surface cas~_ shoe is drilled. R. T. Anders~n -2- TBU C~SRD June 9, 1979 In the event of suspension or ahar~~t please give this office a~te advance notificaticm so that we may bm~ a v.~tness present. ' Very truly yours, O. K. Gilbreth, Jr. Alaska Oil and Gas Conservation ~'ttee Enclosuz~ cc: Department of Fish and C~mm, Habitat Secticm %z/o ~1. De~t of Envimmmmntal Comserva~ w/o croci. Department of Iabor, Supervisor, Labor ~ (~liance Divisicm w/o encl. Union Oil and Gas D on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 Telex' 90-25188 union Robert T. Anderson District Land Manager Mgy 25, 1978 State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska. Application to Drill TBUS G-8 Rd. (42-33) McArthur River Field Gent lemen: Enclosed for your approval are three (3) copies of the Permit to Drill for the redrilling of Trading Bay Unit State G-8. Also enclosed is our Check No. 18793 in the amount of $100.00 to cover the filing fees of this permit. RTA/sk Enclosures Very truly yours, ~rso SUBMIT I.N TRIW TE Form 10-401 ' (Other instruct[ REV. 1-1-71 ~ Ieverse STATE OF ALASKA APl NO. 50-133-20085-01 5. OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN 6. LEASE DESIGNATION AND SERIAL NO. ADL-18730 la. TYPE OF WORK DRILL [~ DEEPEN [] Redri l l 7. IF.'INDIAN, ALLOTTEE OR TRIBE NAME b. TYPE OF WELL OW~I LLL ~ GAS SINGLE MULTIPLE WELL ['~ OTHER ZONE [~ ZONE 8. UNIT FARM OR LEASE NAblE 2. NAME OF OPERATOR " Trading Bay Unit Union Oil Company of California 9. WELLNO. TBUS G-8RD (42-33) 3. AD_DRESS OF OPERATOR P. 0. BoX 6247, Anchorage, AK 99502 10. FIELD AND POOL, 6RWILDCAT McArthur River-Hemlock 4.LOCATION OF WELL Atsurr~c~ Conductor #45, leg #2' 1874'N & 1382'W from SE cor II. SEC.,T,,R.,>~.,(BOTTOS~ "G" Zone of Sec 29, T9N, R13W, S.M. HOLEOB]EC'rIVE) A, pro~,rod.~one Top of Hemlock @3300'N & 2700'W from SE cor of Sec 33, T9_N, R]3W, S.M. Sec 33' T9N, R13W, S.M. 13. DISTANCE IN bIILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. 23 air miles Nlq of Kenai, Afla.ska 14. BOND INFORMATION: B-55372 T~EStatewide S=rety~nd/or~o. Union Pacific Insurance Company · Amount $!00.0.0 15. DISTANCE FROM PROPOSED * [ 16.No. OF ACRES IN LEASE 17. NO.ACRES ASSIGNED LOCATION TO NEAREST [ TO TItIS WELL PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) ,, , 18, DISTANCE FROM PROPOSED LOCATION 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLS TO NEAREST WELL DRILLING, COblPLETED, 12,000'TMD oR APPLIED }:OR, FT. 9,770' TVD Rotary , . 21. ELEVATIONS (Show whether DF, RT, CR, etc.) '22. APPROX. DATE WORK WILL START 99'RI above MSL . 6/10/78 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF' iiOLE SIZE OF CASING ' "WEi611T PER FOOT "GR'~kDE'-- ' SETTING DEPTH Quantity of' cement 12 1/4" 9 5/8" 43 1/2# & N--gO_g~ID.qfiB.'TMD gwiqflnn~n~nnnseH ~i.n.dnu, em , - . '- ~ ....... ' - -- ......... .. 47~ P=]lO cut 8670' to 8730'TMD. .... ~8 1/2". 7" ... 2q~. '"' .._ _N,an ..... Tnn~ R ..... Raft' 7~5 SX .... Btm . , . * . ,, .... PROCEDURE 1. Move rig over conductor #45, leg room #2. 2. Install BOPE as per diagrams #1 and #2 and test to 3000 psi 3. Pull production equipment. 4. Set 9 5/8" cmt. ret. ~10,700' and abandon Hemlock perfs 11,380'-11,790'. 5. Mill section in 9 5/8" csg. at approximately 8670'-8730'. 6. Drill 8 1/2" directional hole to ll,690'TMD, 9770'TVD. 7. Run 1 ogs. IN ~0~ SPACE DESC~BE PRO~SED PROGRAM: If propoml is to deepen ~ve data on present productive zone and proposed new productive zone. I[ pro~l is to drill or deepen dkection~ly, ~ve pertinent data on sub~face locations and measured and ~ue verticM depths. Give blowout preventer pm~am. 24. I hereby certifT~~~thatJ~is True a~orr~t ~ Land ~ ~ES ~ ~o I ~ ~ ~ ~o 'blRECTIONAL SURVEY REQUIRED -' '/ ~ NUM~ CODE 50-133-20085-01 ~ v~s U ~o PERMIT NO. 78-45 ~PROVAL DATE ame 9, 1978 *See InstrUction On ~everse Side PERMIT TO DRILL OR DEEPEN Page 2 PROCEDURE: (Con't) 8. Run and cement 7" liner from 8380' to TD. 9. Clean out 7" liner. Run CBL and gyro logs. 10. Squeeze and test Hemlock for WSO as required. 11. Set 7" perm. pkr @lO,870'TMD. 12. Selectively perforate "G" Zone using casing guns. 13. Run dual tbg. string and place well on gas lift. 14. Selectively inflow perforate Hemlock Zone through tbg. 15. Acidize Hemlock as required. 16. Place well on production producing from gas lifted Hemlock and "G" intervals. NO. "£~IND ~ bl,'ad 'rarru5 a~ ~ho~on. · CHECK VJL .v£ · '/ ~4/r'$LEO FILL UP LI/>" . HYDHiL PiPE RAJ;S HYDRAULIC O;'Er?A TED V.4 L VE : . /" LO-TO~?UE G.4TE OR LO-TO£Q. IE · - NOTE' ALL CHANGE~ MUST HAVE WRITTEt',! APPROVAL BY- THE DISTRICT - . - DRILLING SUPERINTENDEI'~T. ^~'i~'O H B I. i i CHOKE L.t? V4LV£ · -o .../L.P. V~ L V£S ~~ .POSl~V£ . '.. AOdUST~£LF CHOHE I · · U~:.G~.q ~./H furnish · NOTE: /~LL CHANGES I',!UST H&VE WRtTT£N /~.PPROV>,L BY 'THE DISTR',CT DI~ILLI,NG SUPERINTENDENT. .3oo0 o. O~CK LIST '[¥}R NEW WET,T, PERMITS Yes No Rem~Lrks i Is ~e ~_'~_ k fee attach~ ~ ~ ~ 2. Is well to be lccated in a defined pool .... ' · ;e~u< 3. Is a regi?~ered st-~ey plat attached ................ .t.. Is well !,-:_:-:,ted proper distance from property line ......... ~ 5. Is well lo,2a~,ad proper distance from other wells .......... /e>l 6. Is suffici.ent mndedicated acreage available in hhis pool ...... ~1{ Approve Date ~ M ~-- s-: -he ._ -(1) Fee 7. Is well tc., be deviated ....................... /~e)e' - 8. Is operator the only affected party ................ ,~e,}<' 9. Can pe_.rn~t be approved before ten-day wait ........ ~ .... ~,:%~,;~.{ 10. Does operator have a bond in force ................. ~:-~{i Il Is a conservation order needed ................... 12. Is administrative approval needed ................. 13. is conductor string provided .................... 14 Is enough cement used to circulate on conductor and surface · · 15. Will cement tie in surface and intermediate or production strings 16. Will cemeRu cover all knewn productive horizons .......... i7 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 i}:~::,d~'~ psig Approval Recommended: 20. Has D~.4FiM approved Plan of Operation ................ Cmo!ogy: 'r -rr,crr Additional Reguiremen'hs: Revised 4/14/78