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Home My WebLink About181-036 i • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, February 24, 2016 12:53 PM To: 'Juanita Lovett';Trudi Hallett Cc: samantha.carlisle@alaska.gov Subject: RE: Please withdraw Sundry# 315-124/PTD 181-036 - Monopod A-09RD Sundry 315-124 will be withdrawn as requested. Guy Schwartz Sr. Petroleum Engineer 6, AOGCC Sc HNEQ I U 1 907-301-4533 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:jlovettOhilcorp.com] Sent: Wednesday, February 24, 2016 10:52 AM To: Schwartz, Guy L(DOA); Trudi Hallett Subject: Please withdraw Sundry # 315-124/ PTD 181-036 - Monopod A-09RD Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: ilovettPhilcorp.com 1 RBDMS ,,t, FEB 2 5 2016 Tk• rcrOF)t—1 y/,mss, THE STATEAlaska Oil and Gas ,�-��, of Conservation Commission -_ _____ . ALASIc:A ` x= —1w-='---, � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 94., ALASIej' Fax• 907.276 7542 www.aogcc.alaska.gov Trudi Hallett SCANNED ra''''t` 1 Z `� Operations Engineer C ": (2*3�J Hilcorp Alaska, LLC U I 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C, D and E Oil Pools, TB ST A-09RD Sundry Number: 315-124 Dear Ms. Hallett: 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, -1?(4 Cathy P. oerster Chair DATED this 1 day of March, 2015 Encl. RECEIVED • STATE OF ALASKA MAR 0 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 2QAAC 25.280 1.Type of Request: Abandon El Plug for Redrill Cl Perforate New Pod❑ Repair Wel El Change Approved Program❑ Suspend El Plug Perforations❑ Perforate I] PuN Tubing 0 Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing 0 Other. Complete I] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: y St.Irr Hilcorp Alaska,LLC < Exploratory ❑ Development I] • 181-036 ' 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic El Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20062-01 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 93B Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay St/A-09RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 • Trading Bay Field/Middle Kenai C,Middle Kenai D&Middle Kenai E Oil Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ' 7,032 ' 6,495 '5,490 6,550 5,490 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,082' 13-3/8" 1,082' 1,081' 3,090 psi 1,540 psi Intermediate 1,995' 9-5/8" 1,995' 1,992' 6,870 psi 4,760 psi Production 7,020' 7" 7,020' 6,485' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2" 9.2/L-80 4,346' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Ret.Packer&TE-5 SSSV , 4,286'(MD)4,067'(ND)&306'(MD)306'(ND)• 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch C Exploratory ❑ Stratigraphic Cl Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/15/2015 Oil CI ' Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallett@hilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature 'IjAttal Villt Phone (907)777-8323 Date 3/6/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 `�j/ , ' n q Plug Integrity ElBOP Test ( Mechanical Integrity Test 1:1Location Clearance ID Other: 7X- 3 °p ' ? p ---re--:5'1— ( / 1AS. v l VOtl Is;,) Spacing Exception Required? Yes ❑ No t2Subsequent Form Required: /0--Li 09 �� APPROVED BY _ Approved by: - f "' COMMISSIONER THE COMMISSION Date:3-��-�5 OiPJe6J \� SubmFormand Form 10-403(Revised 10/2012) I t�rJ1� for 12 months from the date of approval. Attachments in Duplicate RBDMS V MAR 1 2 2015 /4 2.11-1-- ' • Well Work Prognosis Well: A-09RD Hileorp Alaska,LLCDate: 03/06/2015 Well Name: Monopod A-09RD API Number: 50-733-20062-01 Current Status: Shut-In Producer Leg: N/A Estimated Start Date: March 15, 2015 Rig: Monopod Platform Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 181-036 First Call Engineer: Trudi Hallett (907)777-8323 (0) (907)301-6657 (M) Second Call Engineer: Ted Kramer (907) 777-8420(0) (985)867-0665 (M) AFE Number: Current Bottom Hole Pressure: 2,224 psi @ 5,056'ND Using normal gradient 0.44 psi/ft Maximum Expected BHP: 2,224 psi @ 5,056'ND Max. Allowable Surface Pressure: 1,804 psi (Using .1 psi/ft gradient per 20 AAC 25.280 (b)(4) Brief Well Summary A-09RD is a Tyonek C, D, & E gas lift producer that has been shut-in since 2010 due to low productivity.This workover will consist of pulling the current completion, cleaning out to the top of retainer @ 6,550', re-perfing current zones, and running new gas lift completion. Procedure: 1. Skid rig and RU over A-09RD. 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines and Hilcorp BOPE testing procedures to 250psi LOW and 3,000psi HIGH. 3. RU E-line. Cut tubing above packer at 4,286'. POOH 4. Unseat hanger up to floor height,CBU. POOH laying down completion. Q 5. RIH and clean out to 6,550' and circulate clean. L._��.'S 4. P4 G 6. PU 7" test packer and RIH to +/- 4,200'. Set packer, test backside to 2,500 psi to confirm casing integrity. Hold for 30 minutes, record with a chart recorder. 7. RIH with TCP guns and perforate per program. 8. PU and RIH with gas lift production tubing string w/ packer @ +/- 4275' and hang off same. Test to 1500 psi charting for 30 min. 9. ND BOPE, NU wellhead and test. 10. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram(same) 4. BOP Stack 11 MONOPOD WELL #A-9RD ACTUAL COMPLETION DIAGRAM AS OF 11/18/'01 Current Rig KB Elevation: 39.6' 1 CASING AND TUBING DETAIL 2 SIZE WT GRADE CONN TOP BOTTOM 13-3/8"61 J-55 ARMCO 39.6' 1,082' 382' 9-5/8" 47 N-80 BTC 39.6' 1,995' 7" 29 N-80/P110 BTC 39.6' 7,020' 3 3-1/2" 9.2 L-80 BTC 39.6' 4,346' JEWELRY DETAIL NO. DEPTH ITEM 1 39.6' CIW 11"5M 3-1/2"EUE DCB-T Hanger w/2 "encapsulatedf control line ports. hemicalInj.line MI 4 2 40.22' 3-1/2"mod btc tbg.pup 12.6#L-80 3 305.66' 3-1/2"TE-5 SSSV 4 2,061' SFO-2 GLM 5 5 2,938' SFO-1 GLM 6 3,683' SFO-2 GLM - 6 7 4,173' SFO-2 GLM,Orifice Valve 8 4,223' 3-1/2" BST-C1-1 Chemical lnj.mandrel 9 4,272' 3-1/2" Baker CMU X-O Sliding Sleeve - 7 10 4,286' Baker 47B2 FHL retrievable 7"packer. 11 4,334' 3-1/2" "X"Landing Nipple 12 4,346' Baker W/L re-entry guide w/shear out ball sub am 8 We 9 ii 10 OPEN PERFORATIONS 2 I I TOP BTM SPF ZONE 4439' 4475' 4 C „e—s, 4555' 4590' 4 C 4685' 4752' 4 C 4858' 4920' 4 C 4966' 4983' 4 C 5008' 5028' 4 C 5210' 5244' 4 C 2.72 GR tagged 5307' 5333' 4 C Fill/Junk at 5,490' 5431' 5487' 4 C (10/3/05) 5590' 5631' 4 D 5678' 5699' 4 D Top of Fill/Junk atm 5709' 5771' 4 D 6263'(11/13/'01) 41111P. 5803' 5823' 4 D >Zsv at 6550' 6148' 6244' 4 D 6270' 6310' 4 E(58-1) L 6331' 6405' 4 E(58-1) `TD=7,020' A-09rd Schematic 2005-10-03 Bambang Rachmadi Trading Bay Unit PROPOSED Monopod Platform Well #A-09RD Completion: Future CASING AND TUBING DETAIL Current Rig KB Elevation: 39.6' SIZE WT GRADE CONN TOP BOTTOM 13-3/8" 61 J-55 ARMCO 39.6' 1,082' 382'(KOP) 9-5/8" _47 N-80 BTC 39.6' 1,995' 1 7" 29 N-80/P110 BTC 39.6' 7,020' Tubing: 2-7/8" 6.5 L-80 8rd EUE 39.6' ±4,350' JEWELRY DETAIL . NO. DEPTH ITEM 39.6' Hanger 1 ±300' SSSV 2 ±2,000' GLM z 3 ±3,000' GLM 4 ±3,500' GLM 5 ±4,100' GLM,Orifice Valve 6 ±4,200' Chemical Inj.mandrel 7 ±4,275' Retrievable packer 8 ±4,300' "X"Nipple 9 ±4,350' WLEG 10 6,550' EZSV PERFORATION DETAILS L , ZONE Top(MD) Btm Top Btm SPF Status (MD) (TVD) (TVD) Q 2 C 4439' 4475' 4,200' 4,231' 4' Open r C-5 ±4,439' ±4,475' ±4,200' ±4,231' ±36' Open/Re-Pert C 4555' 4590' 4,301' 4,331' 4' Open 3 C-6 ±4,557' ±4,587' ±4,302' ±4,337' ±30' Open/Re-Perf C-7 ±4,650' ±4,754' ±4,383' ±4,474' ±104' Open/Re-Perf C 4685' 4752' 4,414' 4,472' 4' Open C 4858' _ 4920' 4,654' 4,618' 4' Open C 47-5 ±4,866' ±4,880' ±4,571' ±4,584' ±14' Open/Re-Perf i)5 C 47-5 ±4,898' ±4,917 ±4,599' ±4,616' ±19' Open/Re-Perf C 4966' 4983' 4,658' 4,673' 4' Open 6 C 48-5 ±4,972' ±4,983' ±4,664' ±4,673' ±11' Open/Re-Perf C 48-5 ±5,007' ±5,026' ±4,694' ±4,711' ±19' Open/Re-Perf C 5008' 5028' 4,695' 4,712' 4' Open MIN MI 7 C 5210' 5244' 4,871' 4,901' 4' Open X 8 C 50-3 ±5,210' . ±5,244' ±4,871' ±4,901' ±34' Open/Re-Perf JJ � C 5307' 5333' 4,956' 4,978' 4' Open L J 9 C 50-6 ±5,312' ±5,333' ±4,960' ±4,978' ±21' Open/Re-Perf CZN59S ±5,430' ±5,500' ±5,063' ±5,125' ±70' Open/Re-Pert C 5431' 5487' 5,064' 5,113' 4' Open D 5590' 5631' 5,204' 5,240' 4' Open C 53-0 ±5,601' ±5,631' ±5,213' ±5,240' ±30' Open/Re-Perf = DZNS25 ±5,677' ±5,697' ±5,281' ±5,300' ±20' Open/Re-Pert S D 5678' 5699' 5,281' 5,300' 4' Open D 5709' 5771' 5,309' 5,364' 4' Open M D 53-8 ±5,710' ±5,756' ±5,310' ±5,351' ±46' Open/Re-Pert D 5803' 5823' 4,957' 5,410' 4' Open D 54-5 ±5,806' ±5,822' ±5,395' ±5,409' ±16' Open/Re-Perf D 54-9 ±5,860' ±5,873' ±5,443' ±5,455' ±13' New D 55-7 ±5,938' ±5,954' ±5,512' ±5,527' ±16' New D 56-1 ±6,013' ±6,027' ±5,579' ±5,592' ±14' New EZSV at D 6148' 6244' 5,700' 5,785' 4' Open 6,550' />-<<10 D 57-2 ±6,150' . ±6,202' ±5,701' ±5,748' ±52' Open/Re-Pert E(58-1) 6270' 6310' 5,808' 5,844' 4' Open TD=7,020' E 58-1 ±6,272' ±6,310' ±5,810' ±5,844' ±38' Open/Re-Pert E 58-7 ±6,330' ±6,390' ±5,862' ±5,915' ±60' Open/Re-Pert Updated by: 1LL03/03/15 E(58-1) 6331' 6405' 5,863' 5,929' 4' Open E 60-0 ±6,468' ±6,490' ±5,985' ±6,005' ±22' New Monopod Platform • ii A-9RD Current and Proposed 03/05/2015 Ifilrtmrp 1In.kn.L1.(, Monopod Tubing hanger,CIW-DCB-FBB,11 X A-09 334 3rd lift and 334 8rd susp,w/3" 13 3/8 X 9 5/8 X 7 X 3 34 Type H BPV profile,2-Y.control lines,7"ext neck BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I AMP'olio Valve,Swab,CIW-FL,3 1/8 5M FE, HWO,EE trimValve,Wing,WKM-M, r 3 1/8 5M FE,w/13" ,l♦/, Axelson operator,DD trim I ° I Valve,Upper Master,FMC-120, 3 1/8 5M FE,HWO,EE trim ori 4. -� Iii` 46 , Valve,Master,CIW-FL, 3 1/8 5M FE,HWO,EE trim / '' Adapter,Cameron, 11 5M Stdd X 3 1/8 5M ,I•/ stdd,prepped for 6 Y. • '` neck,3-34 cont control . - iline exit Tubing head,CIW-DCB, iii il iii , Valve,WKM-M,2 1/16 5M 135/83MX115M,w/2- ` FE,HWO,AA 2 1/16 5M EFO,X-bottom `� I „,, i . prep w/1Y:VRprofile I Si Lel•. 4 I•I• ll 01 ti =-_-_- . • iii - �I: Casing spool,CIW-WF, lo 1 1 I III Valve,CIW-F,2 1/16 5M FE, 13 5/8 3M X 13 5/8 3M, s'i p HWO,AAtrim w/2-21/165MSS0 k !° I 1.1111 1Ic>40. VI. Iti Ill - - Ai 'L._ Casing head,Shaffer-KD, ;, 13 5/8 3M X 13"SOW Ili — V bottom,w/2"LPO 0 2"LP plug valve ! Monopod Platform . n 2013 BOP Stack earrlrp.tIa•Ia.1.11. 03/12/2013 Rig Floor 71Bottoof air boot flange J 5'm below rig floor 16" 14.72' 9.50' Pipe flll-11.11.11-1HLW I B 0 0 11111 111 ill 111 111 - 1 3.74' Shaffer yy{}}}�� 13,5//88 5,M{}�,{} Inn 11111. 26.25' f / °I ' .C— Shaffer U(7 2 7/8-5 Variables 2.50' * — 135/8SM �_V:= Blind • II_ 1.76 I'IIIO: hr •1 i , t{ 1�r',i•©.if Mud Cross 111.Ii ha 1x1id ji' �t 135/85M FE FE w/31/85M EFO w/2 1/16 5M Choke and Kill valves w/Unibolt end 1 1-14414/114T connections for lines ��I ��r CIW-U rr��----(( 13585M 2.83' Dual Cameron Flex rams ill 1 I ate. �`. .70' I 1!1 111 1111 111 • Doll deck 14.20" , UOCD 1911 Riser 14.20' i 135/85M FE X135/8SM FE 1 I11 Ili Iii Ii iii iir . 111 111111 111 11 Spacer spool 1.5' 13 5/85M FE X 113M II 111 Ill III 111 Wellhead @ 15.00' i"(~¡=l r.-;'-fI p--.\ cffi ¡-y:;:. ( (l] [ r' [f\\ n /x\ (~j [1/l rj,'\ \, '. ¡ \ ! ~ '¡ ¡ I.'.. ¡'~¡'-. i,'.' ¡,~~ / 1_\ \, I It ,l U '\\ \<"ì 1'\( ,/'!.."-'\ \, I'> >l "~I, / ~,!.~, \ ¡ I l,' ;.," i , ! 'L ¡ ) ',' (-.~~,; lJ L/ 11 Lx l""~= i" u". U ú\J:::J L J\J Q:./ \\ Li \j ./ ¡ , FRANK H. MURKOWSKI, GOVERNOR AI..ASIiA. OIL AM) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 February 3,2004 Dwight Johnson Field Superintendent U nocal PO Box 196247 Anchorage, AK 99519 RE: No-Flow Verification Well A-09RD, PTD 181-036 Dear Mr. Johnson: On January 20, 2004, AOGCC Petroleum Inspector Jeff Jones witnessed a "no flow test" on Unocal's Trading Bay Unit (TBU), Monopod Platform, Well A-09RD. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy. Low volume gas was produced during the test at a rate less than API leakage criteria for subsurface safety valves (900 SCF per hour). No liquid hydrocarbons were produced to surface during the tests. Based on the results of this no-flow test, the subsurface safety valve may be removed from service in TBU Well A-09RD. Unocal must continue to maintain in proper working condition a fail-safe automatic surface safety valve system capable of preventing uncontrolled flow as required in 20 AAC 25.265. If for any reason Well A-09RD becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. Please retain a copy of this letter on the Monopod platform. Sincerely rI' ~~ ~~D. K~A James B. Regg ( ) Petroleum Inspection Supervisor cc : Bob Fleckenstein """"..'.':?','Ü~~~Qit;:¡¡'.;¡ ~~\f'[ì> 1 82004 "-,'.!\~¡n,¡\'{j~~hÇ;,~,,, f" L 13 .. ~ ' , { c(ù Tr Iß\ c; r' rc rñì IT: I~ n IK\ (~ rw f^\ è0 J L~ U lb Lw u- 1h ~ l~~ ~ l~ L#U FRANK H. MURKOWSKI, GOVERNOR AT,ASIiA OIL AND GAS 333W.1THAVENUE. SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 January 26, 2004 Dwight Johnson Field Superintendent Unocal 260 Caviar Street Kenai, Alaska 99611 RE: No-Flow Verification Well A-09RD, PTD 181-036 Dear Mr. Johnson: On January 20, 2004, AOGCC Petroleum Inspector Jeff Jones witnessed a "no flow test" on Unocal's Trading Bay Unit (TBU), Monopod Platform, Well A-09RD. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy. Low volume gas was produced during the test at a rate less than API leakage criteria for subsurface safety valves (900 SCF per hour). No liquid hydrocarbons were produced to surface during the tests. Based on the results of this no-flow test, the subsurface safety valve may be removed from service in TBU Well A-09RD. Unocal must continue to maintain in proper working condition a fail-safe automatic surface safety valve system capable of preventing uncontrolled flow as required in 20 AAC 25.265. If for any reason Well A-09RD becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. Please retain a copy of this letter on the Monopod platform. Sincerely ~B.R&rc James B. Regg ( 1 Petroleum Inspection Supervisor cc: Bob Fleckenstein ~(~ L1, ~,ar&,gt~cr-\', J ~ r,~\i 9~ (i~ 200'& t. ~ßIt"f,'IY.iM'@¡ç;,~,. .. Nh {:.cl t1V. ~ ~' (' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg y". I(ZZ \L¥r DATE: January 20,2004 P.I. Supervisor \ \~ t'( FROM: Jeff Jones SUBJECT: No-Flow Test Petroleum Inspector Unocall Monopod PL T A-09RD PTD-181 0360 Trading Bay Unit January 20,2004: I traveled to Unocal's Monopod Platform in Cook Inlet to witness a No-Flow Test on well A-09RD. Unocal representative Norm Fahnholtz performed the test today in a safe and proficient manner. Well A-09RD was lined up from the tree top swab valve through a 1/2" hose to an Armor-Flow model # 3461-03TO flow meter (180 SCFH to 1800 SCFH span) and terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test and as the data below indicates, well A-09RD meets the AOGCC requirements for a No-Flow status determination. Summary: I witnessed a successful No-Flow Test on Unocal's Trading Bay Unit well A-09RD on the Monopod Platform. Attachments: none ÇÇ¡ Dwight Johnson 1 Greg Geller (Unocal) Unocal Norm Fahnholtz Jeff Jones TBU 1 Mono od PL T Gas 0645 am < 180 seth Start Test 0715 am < 180 seth 0745 am < 180 seth 0815 am < 180 seth 0845 am < 180 seth 0915 am < 180 seth 0945 am < 180 seth End Test Produced to open top container through Armor-Flow meter model #3461-03TO calibrated 1/19/04 Total liquid produced: none "rf" l~ r~[I,' ~G,' fi:, G, ',',", JI ,f¡\ ~\i ~) €,~ 0r1U'¡ O,~ ~~~e't1lj~¡!;;'¡l'/ , ~\..t~'1!J (kQ ~y (..111 I.d' JBJ 02 Page 1 of 1 NO-FLOW Monopod PLT A-09RD 1-20-04 JJ.xls TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 'August 4, 2000 Chris MeYers/Dwight Johnson UNOCAL Field Superintendents 260 cavair Street Kenai, Alaska 99611 Re: No-Flow Verification TBF Well A-09R, PTD 181-036 .. Gentleman: On APril 11, 2000 our inspector ChUck Scheve witnessed a "no-flow test on UNOCAL's Trading Bay Field well # A-09R. Mr. Scheve arrived on location and found both the tubing and the casing bleed off and opened to atmosphere. Both were observed for several hours with no fluid production and only a very slight gas flow. He concluded that TBF well A-09R meets the requirements for "no-flow" status. Trading Bay Field well A-09R (181-036) meets the criteria of a "no-flow" p~rformance test and as such, is considered incapable of unassisted flow to the surface. Under the authority of 20 AAC 25.265(A), it is not required t° have a fail-safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition. If for any reason the well again becomes capable of unassisted flow of hydrocarb°ns,,the subsurface safety valve must be returned to service. Sincerely, .. CCi Dean Geisert Gary Smith Lou Grimaldi Blair E. Wondzell (/ Senior Petroleum Engineer Iqff4bfA-09R · ALASI~A OIL AND GAS CONSERVATION COPlPllSSION TONY ICNOWLE$, G~VERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 .May 12, 2000 Chris Meyers/Dwight Johnson Field Superintendents UNOCAL 260 Caviar Street Kenai, Alaska 99611 R,e~ No-Flow Verification TBF Well A-09RD (2 PTD181-036_--' Gentleman: On April 11, 2000 our Inspector "Chuck Scheve" witnessed a no-flow test On Trading Bay Field well #A-09RD - - PTD # 181-036. When the inspector arrived he found the tubing and casing bled off and opened to the atmosphere. He observed both for several hours while testing safety valves. There was no fluid produced and only a slight amount of gas, which he believed was probably breaking out of the wellbore fluid. The Inspector recommends "no-flow" status for subject well. Trading Bay Field well A-09RD (PTD # 181-036), meets the criteria of a "no-flow" performance test and as such is considered "incapable" of "unassisted-flow". Under the authority of 20 AAC 25.265(A)~ subject well is not required to have a fail-safe automatic SSSV; however, the pilot and surface valve must be maintained in good condition. If for any reason, the well again becomes capable of unassisted flow of hydrocarbons, the subsurface valve must be returned to service. Sincerely, Blair E. Wondzell ~" Sr..Petroleum Engineer CC~ Chuck Scheve Dean Geiser, Monopod Foreman nf-tbfA-9RD MEMORANDUM TO: Robert Christenson, Chairman THRU: Blair Wondzell, P. I. Supervisor FROM: Chuck Scheve, d.. 5 Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 11,2000 SUBJECT: No Flow Trading Bay field Tuesday, April 11, 2000: I traveled t© Unocal's Monopod Platform and witnessed a no- flow test on well A-09RD. I ardved on location and found both the tubing and casing bled off and opened to atmosphere. Both were observed for several hours, while testing Safety Valve Systems, with no fluid and only a very slight gas flow (probably gas breaking out of wellbore fluids) noted. I recommend Well A-09RD on the Monopod Platform be approved as a no flow for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Well A-09RD meets the AOGCC requirements for no flow status. Attachments: X Unclassified Classified Unclassified with Document Removed No Flow TBF Monopod 4-11-00 CS Unocal North Americ~ Oil & Gas Division Unocal CorpOration P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear MS. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Regzonal Drilling Manager GSB/lew APR 2 199!) IDiI & 6as Cons. Comml~bll ,. CONDUCTOR . l0 ll 12 13 14 15 16 17 18 19 20, 21 22 25 26 27 28 29 3O 31 32 ' 'R1 3W MONOPOD CENTER FROM SOUTHEAST CORNER' SECTION 4' T9N'...~/~!,~ "Y" = 2 523 126 · LAT. : 60°53' ' ' , ,,'~ "X'' = 218,871 LONG. "Y" COORD. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,113.2 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133.8 2,523,137.6 2,523,138.8 2,523,138.8 2,523,137'.2 2,523,132.8 2,523,129.4 2,523,132.0 2,523,128.4 ,.?, 52,3~.P_.J.. .R .- ~ 2,523,133.9 2,523,120.9 2,523,131.4 2,523,118.1 2,523,127.2 2,~23,123.6 2,523,120.0 2,523,122.6 2,523,119.2 "X" COORD. 218,880.9 218,883.2 218,883.9 218,883.2 218,881.3 218,876.8 218,873.0 218,869.0 218,864.6 218,861.1 218,858.8 218,858.1 218,858.8 218,860.7 218,865.2 218,869.0 218,873.0 218,877.4 218,875.7 218,878.6 218,870.8 218,873.9 .~ ?.1 R. ,q7R. q 218,867.0 218,878.1 218,863.9 .2!8,875.0 218,865.1 218,868.1 218,871.1 218,863.4 218,866.3 WELL # FSL FEL ,,.i....,-.,= A-28 1621 554 A-25 1617 551 A-30 1612 551 1608 551 A-27 1605 '553 , A-23 .1601 557 A-21 and RD 1600 561 A-22 1600 565 A-14 1601 570 A-13 1604 573 A-17 1608 576 A-8 1612 577 A-15 1616 577 A-24 and RD 1620 574 A-29 1624 570 A-9 and RD 1625 566 A-19 1625 562 A-18 1624 558 A-11 1619 559 A-3.. 1616 556 A-1 1618 564 A-7 1615 561 A-4 1611 558 A-6 1600 ' :568 A-32 1607 556 A-12 and RD 1617 571 A-20 1604 559 A-2 1613 57O' A-16 1610 566 A-26 1606 563 A-10 1609 571 A-5 and RD 1605 568 1 &2 STATE OF ALASKA /'-%SKA elL AND GAS CONSERVATION COM, ~ION REPOFII OF SUNDRY WELL OPERATI(30 I I Ill [ 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pedorate __ Pull tubing Alter casing __ Repair well ~. Pull tubing __ Other 2. Name of Operator Union 0il Company of California (UNOCAL) 3. Address P.O. Box 190247, Anchorage, AK 99519-024] 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1625'N & 566'W from SE corn, SeC 4, TgN, R13W, SM 6. Datum elevation (DF or KB) RT 101' MSL 7..Unit o,r. Propejty na~,e , ~raa~ng pay btate 8. Well number TBS A-gRD At top of productive interval 4439' MD, 4200' TVD, ~effectivedepth 6471' MD, 5988' TVD, Attotaldepth 7032' MD, 6495' TVD, 123'S & lO04'W F/Surf Loc. 148'S & 1966'W F/Surf, Loc. 144'S & 2204'W F/Surf. Loc. 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 7032 feet 6495 feet 6471 rem 5988 feet Plugs (measured) Junk (measured) Length 9. Permitnumber/approvalnumber 81-36/9-057 10. APInumber 50-- 733-20062-01 feet Size Cemented Measured depth 1082' 1995' 7020' 13 3/8" 9 5/8" 7" Driven 650 sxs 100 sxs 1082' 1995' 7020' See AttaChed 11. Field/Pool Trading Bay - C&D Pools True vertical depth 1081' 1992' 6485' trUe vertical Tubing (size, grade, and measured depth) 2 7/8", 6.41f N-80 $ 4382' Packers and SSSV (type and measured depth) Otis "BWD" Packer $ 4335 ' SSSV $ 295' 13. Stimulation or cement squeeze summary RECEIVED AUG 3 o See Attached Intervals treated (measured) Treatment description including vOlumes used and final presSure Alaska 0il & Gas Cons, C0mmissi¢ Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation LS: SS: Subsequent to operation S±ngle: 15. Attachments Copies of Logs and surVeys run._..,,_ Daily Report of Well Operations ~ 42 127 55 1085 PSI 146 457 537 1085 PSI 264 1518 1356 640 PSI 16. Status of well classification as: Oil z~ Gas __ Suspended __ 85 PSI 155 PSI 355 PSI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/f~~, /~-~---'~ ~t,~ Title Environmental Engineer Form l~-J~e~/0~ts Service Date 08/~/89 SUBMIT IN DUPLICATE 1 ..J 2 / / / ! I _J -- 082' 9-5/8" 47// N-80 @ 1995' 7" 29# P-110 & N-80 @ 7020' TUBING DETAIL 2-7/8", 6.4#, N-80 TBG BT&C. 1) SSSV @ 295' 2) FIVE GLM'S 3) XA SLV @ 4300' 4) OTIS "BWD" PKR @ 4335' 5) X NIPPLE @ 4569' 6) WL RE-ENTRY GUIDE @ 4581' IICII ZONE INTERVAL 4459'-4475' 4555'-4590' 4685'-4752' 4858'-4920' 4966'-4983' 5008'-5028' 5210'-5244' 5507'-5555' 5431'-5487' "B" ZONE INTERVALS 5590'-5631' 5678'-5699' 5709'-5771' 5803'-5825' 6148'-6244' 6270'-6310' 6331'-6405' JUNK @ 6471' ETD CMT RET @ 6550' RE£E'iVI 'AUG o t98 Alaska Oil & Gas Cons. Anchorage WELL TBS A-9RD PRODUCER WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL SCALE: NONE DATE: 6-50-89 D ~mmission MONOPOD TBS A-9 RD PERFORATION RECORD AUGUST 17, 1989 DEPTH MD DEPTH TVD SAND INTERVAL FEET 4439 - 4475 4200 - 4232 I! C II 36 4555 - 4590 4258 - 4331 35 4685 - 4752 4414 - 4472 67 4858 - 4920 4565 - 4618 62 4966 - 4983 4659 - 4674 17 5008 - 5028 4696 - 4713 20 5210 - 5244 4871 - 4902 34 5307 - 5333 4956 - 4979 26 5431 - 5487 5064 - 5114 56 5590 - 5631 5203 - 5240 IIDII 41 5678 - 5699 5282 - 5300 21 5709 - 5771 5309 - 5364 62 5803 - 5823 5392 - 5410 20 6148 - 6244 5699 - 5785 96 6270 - 6310 5808 - 5844 40 6331 - 6405 5863 - 5929 " 74 UNION OIL CO. OF CALIFORNIA Drilling Record Page No. i . LEASE TRADING BAY STATE WELL NO. A-9 RD FIELD MONOPOD PLATFORM DATE 04/07/89 04/08/89 04/09/89 04/10/89 04/11/89 04/12/89 04/13/89 ,,, E.T.D. DETAILS OF OPERATIONS,.,,DESCRIPTIONS & RESULTS MIRU RIG 56 ON A-9RD. RU MYERS WIRELINE ON LS. TEST LUBRICATOR-OK. RAN SCRATCHER TO BV @ 334'. PULLED SAME-OK. RAN SCRATCHER TO 5550'. OPENED XA @ 4365' LS. PULLED BV IN SS FROM 335'. CIRC DOWN LS & UP 7" ANNULUS-OK.. CLOSED XA @ 4365' LS. COULD NOT SHIFT "XA" @ 5528'. PUMPED A LITE SAL PILL DOWN SS TO "D-E" ZONES. DETERMINED THAT XA @ 5528' WAS AN XO. OPENED SAME. CIRC THROUGH LS UP SS. SQZ'D "C" ZONE PERFS W/LITE SAL. INSTALLED BPV'S. ND TREE. / CONTINUE ND TREE. NU & TST BOPE.. UNSEATED TBG HANGER. 7" BAKER PKR WOULD NOT RELEASE. PULLED 80% OF TBG YIELD-PKR WOULD NOT RELEASE. RAN APRS 1-23/32" JET CUTTER. CUT 2-3/8"LS @ 4415'. MADE 2ND CUT ON LS ~ 4352'. CUT SS ~ 4386'. RD WIRELINE. CIRC BOTTOMS UP. POOH, LAY DOWN 2-3/8" TBG (RECOVERED 4358.58 SS & 4354.36' LS). RIH W/6" BIT & 7" CSG SCRAPER TO 2503'. CIRC BOTTOM' UP. POOH. RIH W/7" HOWCO MODEL "3L" BRIDGE PLUG. SET 7" HOWCO BP @ 2127'. TEST TO 1200 PSI-OK. POOH. SANDED OUT BP WITH 3 SXS SAND. BLED 9-5/8" X 7" ANNULUS PRESSUE TO 0 PSI. TST PACKOFF TO 1500 PSI-OK. ND BOPE. CHNG OUT TBG SPOOL W/NEW 13-5/8" 3M X 11" 5M TBG SPOOL. TST SAME T/3000 PSI-OK. NU & TST BOPE-OK. INST WEAR BSG. RIH. CIR OUT SAND. RETRIEVED 7" HOWCO BP. RIH W/FISHING'TOOLS. RIH TO TOF @ 4356'. ENGAGED SAME. PULLED 40,000# OVER-NO SUCCESS. PULLED OFF @ 65000#. POOH. RECOVERED 2 PIECES OF 2-3/8" TBG (1.37' TOTAL). RIH W/OVERSHOT W/O -. SUCCESS. 'TRIPPED FOR 6" STABILIZED JUNK MILL. MILLED 4358'-4359'. TRIPPED FOR IMPRESSION BLOCK. POOH. SHOWED 2 EVEN TBG TOPS SIDE BY SIDE. RIH W/3-5/8" OD OVERSHOT. ENGAGED FISH $ 4359'. PKR WOULD NOT RELEASE. RU WIRELINE. DETERMINED THAT SS WAS ENGAGED. DID BLIND BACK OFF. RECOVERED 19.4' OF SS. RIH & ENGAGED LS @ 4359' W/5-3/4" OVERSHOT. RECOVERED PKR, ALL OF SS & LS CUT OFF. RIH W/5-3/4" OVERSHOT W/TC MILL CONTROL. H008 UNION OIL CO. OF CALIFORNIA Drilling Record Page No.... 2 LEASE TRADING BAY STATE WELL NO. A-9 RD FIELD MONOPOD PLATFORM. DATE E.T.D. DETAILS.OF OPERATIONS, DESCRIPTIONS &.RESULTS 04/14/89 04/15/89 O4/16/89 04/17/89 04/18/89 CONTINUE RIH W/5-3/4" OS & ENGAGED FISH ~ 4418'. JARRED ON FISH-FISH MOVED UP THE HOLE 9' DURING 11-1/2 HRS OF JARRING. RU SCHLUMBERGER & RAN 1-13/16" JET CUTTER. CUT TBG BELOW OS AT 4416'. REC 6.67s OF 2-3/8" TBG. RIH W/5-3/4" OS & FISHING TOOLS. ENGAGED FISH @ 4416'. RU SCHLUMBERGER. RIH W/FREE POINT-TOOL FAILED. POOH & ADJUST SPRINGS. RAN FPI-SHOWED 100% FREE IN STRETCH TO 5545' (USING 40-60M# OVERPULL) & 100% STUCK AT 5555s· RAN 1-13/16" JET CUTTER & ATTEMPT TO CUT TBG AT 5520s-CUTTERDID NOT FIRE. TRIP FOR NEW CUTTER & CUT TBG AT 5520~· COULD NOT JAR LOOSE. ATTEMPED TO CLOSE "XA" SLEEVE AT 44Z0~-TOOL WOULD NOT LATCH. MADE BACKOFF USING STRING SHOT AT 4536s· RD SCHLUMBERGER. POOH & REC 117' OF FISH (2-3/8" CUTOFF, 2-3/8" XA SLEEVE-OPEN, 50' CARBIDE BLAST RINGS, XO, 2-7/8" TBG & PUPS). RIH W/5-3/4" OS ON 3-1/2" DP & ENGAGED FISH ~ 4533~. COULD NOT JAR LOOSE. RIH W/JET CUTTER & CUT TBG @ 5180'. CIRC & POOH-REC 644~ OF 2.-7/8" TBG & CARBIDE BLAST JOINTS. RIH W/5-3/4" OS-HOLE WAS TIGHT AT 4580'. CIRC & POOH. RIH W/6" STABILIZED JUNK MILL & CLEANED OUT SCALE IN CASING 4421s TO 4628~. TRIP FOR BIT. RIH W/6" BIT & CLEANED OUT CSG 4628'-5176'. CIRC & POOH. RIH W/5-3/4" OS W/HOLLOW MILL CONTROL (TIGHT 4845~ & 4966'). REAMED 4966~-5177.~ & ENGAGED FISH. JARRED ON FISH-NO MOVEMENT AFTER 4 HRS. RU SCHLUMBERGER & APRB & MADE BACK OFF,USING STRING SHOT ~ 5197'. CIRCE POOH. REC 16.84' OF 2-7/8" TBG. RIH W/OS ON 3-1/2" DP RIH W/OS & REAMED 5177~-5197'. ENGAGED FISH ~ 5197s. RU SCHLUMBERGER & APRS & RIH W/2-1/4" JET CUTTER. CUT TBG FISH @ 5368~ WLM. CIRC & POOH-REC 170.54~ OF TBG & CARBIDE BLAST JTS. RIH W/6" BIT & REAM 5192'-5363'. CIRC.CLEAN & POOH. TSTD BOPE. RIH W/5-3/4" OS & ENGAGED FISH @ 5363~ DPM. H008 UNION OIL CO. OF CALIFORNIA Drilling Record Page No. 3 LEASE TRADING BAY STATE WELL NO. A-9 RD FIELD MQNOPOD PLATFORM DATE E. T. D. 04/19/89 04/20189 04/21/89 04/22/89 04/23/89 04/24/89 .DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JARRED ON FISH W/40-65,000# OVERPULL. TOP OF FISH ~ 5363' & CUT @ 5520'. NO MOVEMENT. ATTEMPTED BACKOFF W/STRING SHOT @ 5421', JARRED FREE & POOH. RECOVERED 22.12' OF FISH (TOF @ 5385'). RIH W/6" MILL, TAGGED FILL @ 4625' & CLEANED OUT TO 4915'. CLEANED OUT W/6" JUNK MILL 4915'-5385' (TOF). CIRC & POOH. RIH W/REVERSE CIRC JUNK BASKET TO 5385'. CIRC W/HI-VIS POLY SWEEP WHILE WORKING JUNK BASKET. POOH-NO REC. RIH W/6" DRAG-TOOTH WASH SHOE ON 5-3/4" WASHPIPE. REAMED 4615'-4986'. COULD NOT GET DEEPER. POOH & LAID DOWN WASHPIPE. RIH W/6" MILL & CLEANED OUT TO 5385'. CIRCULATED & POOH. MADE UP 5-7/8" WASH SHOE & 5-1/2" WASH PIPE & RIH. WASHED OVER FISH & CLEANED OUT TO 5504'. POOH & MADE UP 5-3/4" OVERSHOT & FISHING TOOLS. RIH & ENGAGED FISH @ 5388'. JARRED FISH LOOSE & POOH. RECOVERED 131.03' OF FISH. RIH W/REVERSE CIRCULATING JUNK BASKET & CLEANED OUT TO 5514'. POOH & MADE UP 5-3/4" OVERSHOT & FISHING TOOLS. RIH & ENGAGED FISH @ 5516'. JARRED FISH LOOSE & POOH. RECOVERED REMAINING FISH TO TOP OF PACKER. MADE UP 6" MILL & RIH TO 5555'. CLEANED OUT TO 5559' & POOH. MADE UP PACKER PLUCKER & RIH. ATTEMPTED TO STAB INTO PACKER BUT UNABLE. POOH & MADE UP 6" MILL. RIH & MILLED TO 5563' AND PACKER FELL FREE. CHASED JUNK TO 6157 & MILLED TO 6177'. CLEANED oUT TO 6239' & MILL STOPPED. TRIPPED FOR A NEW MILL. CONTINUED CLEANING OUT TO 6478'. POOH & MILL WAS 5/8" OUT OF GAGE. JUNK BASKETS FULL OF CARBIDE. RIGGED UP WIRELINE & RAN 5.778" GAGE RING TO 4950'. MADE UP CEMENT RETAINER & SET AT 4872'. PERFORATED FROM 4852'-4854'. RIGGED DOWN WIRELINE. H008 ' UNION OIL CO. OF CALIFORNIA .... Drilling Record Page No. 4 LEASE TRADING BAY STATE WELL NO. A-9 RD FIELD..MONOPOD PLATFORM DATE E.T.D? DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 04/25/89 04/26/89 04/27/89 04/28/89 RIH W/CEMENT RETAINER & SET AT 4812'. CIRCULATED, CLEAN, STABBED INTO RETAINER & TESTED THE ANNULUS TO 1000 PSI. ESTABLISHED BREAKDOWN AT 3300 PSI & .75 BPM. MIXED & PUMPED 200 SXS CLASS "G" W/.5% HALAD 544, .2% CFR-3 & 1% LWL. FINAL INJECTION PRESSURE WAS 2900 PSI @ .5 BPM. CIP @ 0358 HRS. POOH & MADE UP 6" BIT & SCRAPER. RIH & CLEANED OUT TO 4800'. RIGGED UP WIRELINE & PERFORATED FROM 4760s TO 4762s. RIH W/CEMENT RETAINER & SET AT 4729~· CIRCULATED, CLEAN, STABBED INTO REAINTER & TESTED THE ANNULUS TO 1000 PSI. ESTABLISHED BREAKDOWN AT 2600 PSI & 1.5 BPM. MIXED & PUMPED 300 SXS CLASS "G" (W/ABOVE ADDITIONS). FINAL INJECTION PRESSURE 2550 PSI & .4 BPM. CIP @ 1926 HRS. POOH. PERFORM BOPE TEST. FINISHED TESTING THE BOPE. RIH W/7" PACKER & SET @ 4394~· 'TESTED THE CSG ABOVE THE PERFORATIONS TO 1500 PSI-OK. POOH & PICKED UP 6" BIT. RIH & DRILLED CEMENT & RETAINERS TO 4872~. POOH FOR NEW BIT. RIH & DRILLED THE CEMENT RETAINER AT 4872'. CLEANED OUT TO 6471~. POOH & PICKED UP 7" SCRAPER. RIH OPEN ENDED & PUMPED 30 BBLS HEC-FIW W/25# SAND'FOLLOWED BY 50 BBLS OF FIW W/1/2 BBL FLOCULANT. PUMPED FIW UNTIL CLEANED. CLEANED OUT MUD PITS. FINISHED CLEANING MUD PITS. CHANGED OVER WELL TO CLEAN FILTERED INLET WATER & 3% KCL. POOH & MADE UP TBG CONVEYED PERFORATIONG GUNS. RIH. H008 -._. UNION OIL CO. OF CALIFORNIA Drilling Record Page No. 5 LEASE..TRADING. BAY. STATE WELL NO. .A-9 RD FIELD t{ONOpOD PLATFORI~. DATE E. T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 04/29/89 04/30/89 o5/1/89 C ZONE: 4439'-4475' 4555'-4590' 4685'-4752' 4858'-4920' 4966'-4983' 5008'-5028' 5210'-5244' 5307'-5333' 5431'-5487' RIH W/4-5/8" GUNS, FILLED TBG W/WATER EQUIVALENT TO 1500 PSI & TESTED EQUIPMENT. RIGGED UP WIRELINE, RAN GAMMA RAY & PLACED GUNS ON DEPTH. SET PACKER ~ 4400' & PERFORATED THE FOLLOWING ZONES: D-ZONE: 5590'-5631' 5678'-5699' 5709'-5771' 5803'-5823' 6148'-6244' 6270'-6310' 6331'-6405' DROPPED THE BAR & FIRED GUNS. PRESSURE BUILT TO 300 PSI ON TUBING. CIRCULATED & POOH. MADE UP 6" MILL & SCRAPER & RIH 6438'. WORKED MILL DOWN TO 6442'. JARRED FREE. POOH. MILL PLUGGED W/SCALE. MADE UP 6" BIT & RIH. CLEANED OUT 6438'-6471' (SAND, PERF. J SCALE). POOH & MADE UP 7" PACKER. RIH, SET @ 4335' & TESTED ANNULUS TO 1000 PSI. POOH & LAID DOWN SETTING TOOLS. RAN 2- TUBING & GAS LIFT VALVES (G/L MANDRELS @ 4261' 3735' 3266' 2181' & 1037'). STABBED INTO PACKER & SPACED OUT. LANDED 2-7/8" COMPLETION. REENTRY GUIDE ~ 4381', 2-7/8" X NI @ 4369' PERM PKR,9 4335' XA SLEEVE ~ 4300' GAS LIFT VALVES PER PREVIOUS REPORT & BV NIPPLE @ 295'. TST SEAL SECTION T/5 PSI-OK. ND BOPE. NU & TEST CIW 3-1/2" X 10"-5M SINGLE TREE T/5000 PSI-OK. PULLED BPV. RETURNED WELL T/PRODUCTION @ 080 HRS. RELEASED RIG ~ 1200 HRS 5/1/89. H008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLI TION FOR SUNDRY APPROVAIL GIN [ 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter Casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Variance __ Perforate __ Other Change approved program __ Pull tubing ~ __ 2. Name of OPerator . ti 5. Type of Well: . 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL)./ Development~ RT 101' MSL Exploratory __ 3. Address .J Stratigraphic __ 7. Unit or Property name P.O. BOX 190247' Anchorage, AK 99519-0241 Service__ Trading Bay State feet 4. Location of well at surface 1625'N & 566'W from SE corn, Sec 4, T9N, R13W, SM At top of productive interval 4439' MD, 4200' TVD, 123'S & lO04'W F/Surf Loc. At effective depth 6471' MD, 5988' TVD, 148'S & 1966'W F/Surf. Loc. At total depth 7032' MD~ 649.5' TVD ¢ 144' S & 2204 ~ W F/Surf. Loc. 12. Present well condition summary Total depth: measured 7032 feet Plugs (measured) true vertical 6495 feet 8. Well number TBS A-gRD 9. Permit number 81-36 10. APl number 50-- 733-20062-01 11. Field/Pool Trading Bay - C&D Pools Effective depth: . measured 6471 feet Junk (measured) true vertical 5988 feet Casing Length Structural Conductor Sudace 1082 1995 Intermediate 7020 Production Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 3/8" Driven 1082' 1081' 5/8" 650 sxs 1995' 1992' 7" 100 sxs 7020' 6485' See Attached true vertical Tubing (size, grade, and measured depth) 2 7/8", 6.4# N-80 $ 4382' Pac~rsandSSSV¢ypeandmeasureddepth) Otis "BWD" Packer SSSV ~ 295' RECEIVED AUG 3 o 1989 Alaska 0ii & Gas Cons. C0mmlsd0~l Anchorage 13. Attachments Description summary of proposal __ Detailed operations program m BOP sketch 14. Estimated date for commencing operation m, 16. If proposal was verbally approved Name of approver Date approved Service "'17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~,./~./,~..~.~/ ~~ Title Environmental Engineer F~ov//D. Roberts ' 0 FOR COMMISSION USE ONLY Conditions of'approval: Notify Commission so representative may witness Plug integrity m BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- 15. Status of well classification as: Oil .~ Gas __ Suspended Date Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY t,; ..Q~t~lE C. SMITH o8/ /8 JApproval NCC., ~ ,~/~ Approved Copy Returned .... Commissioner Date SUBMIT IN TRIPLICATE TRADING BAY STATE A-9 REDRILL WORKOVER PROCEDURE 1) MIRU. KILL WELL. NIPPLE DOWN TREE. INSTALL AND TEST BOPE. 2) RECOVER EXISTING SINGLE COMPLETION AND PERMANENT PACKER AT 4395'. 3) CLEAN OUT TO 6471' ETD. 4) SQUEEZE CEMENT PERFORATIONS FROM 5307' TO 5333'. 5) RUN A SINGLE 2-7/8" COMPLETION. 6) RIG DOWN AND MOVE OFF, PLACE WELL ON PRODUCTION. ESTIMATED TIME: 6 DAYS NOTE: SHOULD H2S BE ENCOUNTERED, UNOCAL WILL CONFORM TO ALL REQUIREMENTS AS SET FORTH IN 20 AAC 25.065. ANTICIPATED SBHP: 1950 PSI RECEIVED AUG o t989 Alaska 011 & Gas Cons. Commission Anchorage MONOPOD TBS A-9 RD PERFORATION RECORD AUGUST 17, 1989 DEPTH MD 4439 - 4475 4555 - 4590 DEPTH TVD 4200 - 4232 4258 - 4331 SAND II C Il INTERVAL FEET 36 35 4685 - 4752 4414 - 4472 67 4858 - 4920 4565 - 4618 62 4966 - 4983 4659 - 4674 17 5008 - 5028 4696 - 4713 20 5210 - 5244 4871 - 4902 34 5307 - 5333 4956 - 4979 26 5431 - 5487 5064 - 5114 56 5590 - 5631 5203 - 5240 IIDII 41 5678 - 5699 5282 - 5300 21 5709 - 5771 5309 - 5364 62 5803 - 5823 5392 - 5410 20 6148 - 6244 6270 - 6310 5699 - 5785 5808 - 5844 96 40 6331 - 6405 5863 - 5929 74 Alaska Oil & Gas Cons. commisslon Anchorage ~3-3/~" 082' / 9--5/8" 47# N-80 @ 1995' 7" 29# P-110 & N-80 @ 7020' TUBING DE-I'AIL 2-7/8", 6.4-J, N-80 TBG BT&C. 1) SSSV @ 295' 2) FIVE GLM'S 5) XA SLV @ 4500' 4) OTIS "BWD" PKR @ 4555' 5) X NIPPLE @ 4569' 6) WL RE-ENTRY GUIDE @ 4-381' "C" ZONE INTERVAL "D" ZONE INTERVALS 4459'-4475' 4555'-4590' 4685'-4752' 4858'-4920' 4966'-4985' 5008'-5028' 5210'-5244' 5307'-5333' 5431'-5487' 5590'-5651' 5678'-5699' 5709'-5771' 5805'-5825' 6148'-6244' 6270'-6510' 6551'-6405' RECEIVED CMT RET @ 6550' AUG 3 0 1989 Alaska 0il & Gas 6ons, Anchorage WELL TBS A-9RD PRODUCER WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (db<::] UNOCAL) DRAWN: CLL SCALE: NONE DATE: 6-50-89 .FROM UNOCRL MONOPOD 4.1:2.1989 10129 P. 1 '~tr,_--'"~ ~';' ............. , ....... U OPERAT. IONS RECEIVED ALASKA DISTRICT .. : TRANSMITTAL '" ;'~'~' T O1... '~' ". Alaska Oil & Gas Cons. Commission · Anchorage';~l;.it,. - '- . '- - .... ':~ ...... ~:,u .......... . ~.l FROM: NO. OF PAGE {INCLUDING THIS PAGE) ' CONTACT: ........ . ....... , ..... EXT:_ OFFICE (907) FAX (907) FROM UNOCAL MONOPOI) r ~/~ 4.12.1989 10~30 P. 2 ~ud Vi~ut_! Oas DeceoCoro RtL ,,/ :='-' ii Audio piti_..' .._ ACcm~,:A~.oR Full Charse ~reeeuy~._~_..c~X3 ......... I P~pe Rams___ .. , -- Blind Rams Choke Llne Valv&~__. H,C,~o Valve== . ..... - ....... Cheek Valve -., ,. ,.- ---~.~. __ Adjustable Chokes .... --- --------~----,, 'auleall )eraSed ohok, '2. ~epatt' or Replacement of ta~led equipment to be made within .~-'~-.-; ~ % ...... .. Lo'ae~ Kelly v/ Teat Fteslu~'e 1~0 ~ ~ ~o. ValveL=:_3~'.,. '- : .... .... _~ days and Inspector/ OtiS; - AO&OCC ac - Sups~viaot R,E'CEIVED Alaska Uti & Gas Cons. COlllfllJSSiOfl Anchorage STATE OF ALASKA A~KA OIL AND GAS CONSERVATION COMMI~,~iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend--- Alter casing __ Repair well Change approved program __ Pull tubing __ Variance __ 2. Name of Operator Development __ Un-ion 0-[1 Co. of Cal-if. (Unocal) Exploratory__ 3. Address Stratigraphic __ P.O. Box 19024.7~ Anchorage~ Ak. 99519 Service__ 4. Location of well at surface At top of productive interval At effective depth Operation shutdown __ Re-enter suspended well __ Plugging -- Time extension __ $timulate __ Perforate __ Other __ At total depth 1625' N 566'W from'SE Corner, R13W, SM 123' S and 999' W of surface 6. Datum elevation (DF or KB) (KB) 101 feet 7. LI,0it or.l~ropertyA3am.e .... f~ ~onopod" Flattorm 149'S and 1970' W of surface 1530'N and 2700' W from SE T9N, R13W, SM 7032 . feet 6495 feet 12. Present well condition summary Total depth: measured true vertical Sec 4, T9N, Corner, Sec. 4, 8. Well number A-9RD 9. Permit number 81-36 10. APl number 50-- 733-20062-01 11. Field/Pool rradin~ Bay - C&D Pools PlugS(measured) Top of Cement plug @ 6480' Cement Retainer at 6550' Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth 10.82' 1995' 7020' 6480 ~m 5996 ~et Junk (measured) Size Cemented Measureddepth 13-3/8" Driven 1082' 9-5/8" 650 sxs 1995' 7" 100 sxs 7020' True vertical depth 1081' 1992' measured Top Interval 4428' Bottom Interval 6900' trueveRical Top Interval 4191' Bottom Interval 6376' 6485 ' iECEIVED Tubing (size, grade, and measured depth) 2'7/8" 6.5#, 2-3/8'' 4.6# N-80 @ 5598~-~$~.,OJl,& GasCons. C0mrais$i0a · 2-3/8" 4.6# N-80 @ 4427' '*"~;..,'~a, ll¢~0tag8 Packers and SSSV (type and measured depth) Baker A-5 Dual Packer @ 4403'." Baker "D" @ 5554' SSSV: LS @ 334'i SS @ 335' 13. Attachments Description summary of proposal ..~ Detailed operations program __ BOP sketch ~ 14. Estimated date for commencing oPeration February, 1989 i 15. Date approved · 16. If proposal was verbally approved Name of approver Status of well classification as: Oil 3f Gas_ Service R.D. Roberts Title Environmental Engineer FOR COMMISSION USE ONLY 17.' I hereby certify th ~a.t,the foregoing is true and correct to the best of my knowledge. Signed. Suspended __ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission&,~NNIE C, SMITH -~po,'oved Copy Returned /- ~- ~COm-'~i ibissioner [Approval NO. ¢ ~ ~,~ ¢ Date Form 10-403 Rev 06/15/88 SUBMITIN TRIPLICATE 1~' .,~ 4,0 HYDRAULIC' ICHOKE . MANIFOLD !SEE DRAWING TO MUD PUMPS & cEMENT UNIT ~ t, HYDRIL -' . ,..~ PIPE F'..:, M S ANGLED FILL UP LINE ._~~ PIPE RAMS II II #. _ G'~"E. GATE (i t" GATE GATE .J~_/__Z~~ KILL LINE OM MUD PUMP, & CEMENT UNi- ~ BLIND RAMS · CONTRACTOR FURNISHED OPERA TOR FURNISHED WELL NAME: RIG CONTRACTOR: RIG' STACK PRESS ;,IRE RA TING: CHOKE' LINE .SIZE & NOTES: 1. HYDRAULIC VALVES OPEN AUTOMATICALLY WHEN DIVERTER IS CLOSED. NOTE: ALL CHANGES MUST HAVE WRITTEN AFPROVAL BY THE DISTRICT DRILLING SUPF_.RtNTENDENT DEPT. APPROVAL 2. FLEX HOSE (fi/) IS TO BE USED IF NECESSARY WITH. DDS' APPROVAL. JAF[ 2 ,'/~l.q.;: ~.51~g ~i! l Oas Cons'~ Commis$ior~ _$_, 5. L4,;__5,L2BY_8_6_ i ALL 5/8"-- E OF _r= ST'AC'-'" 5M OF: iOM WORK OV.E.F: OPERATIONS UNION OIL COt,,':.:-',.- ':' OF CALIFORNIA t : '18 VII - 01/21/88 '-(" T,B.S. A - 9., ,u,,, OVER .- - -- .... -' ' CASING & ABANDONMENT DETAI; C C-6 Sd.__--- Sd, 50-3 Sd. ! 51-6 - Sd, ~ ' R.T. II, CIW BCB Tubing Hangar 12", 3000# x 7 1/16" ~0C0# O 37. III. 1) 3/8", 61#, 3-~5 Butt csg O 1,C~2'(:mtd w/12QOsx) .IV.' 9 ~/8", ~7~, N-BO Butt csg. O l,~' (cmt'd w/6~O sxs) V, Top of cement plug vi. Csment Retainer · 6,~0' 7" 2~, '~-lI0 & N-80 TUBING DETAIL " 2 7/8",6,5~ & 2 3/8' 4.6~,N-80,BUTT. TUBING ~. 0tis XEL Ba~I Valve N~I~ ~ ~.22' " '' 15. 16. 17. 20. 2i. 22. 2 3/8" Side Pocket G.L.M. 4~]1 2 ~/8" Otis "XA" 5!aeve Baker No<el "~-5" ~1 Packe~ 440].2~' 2 ~/8" Otis "XA" Sleeve 2 3/8"x2 7/8" Buttress Cross-over ~ ~24.1~' 2 7/8"xl )/8" 8utt:ess C~css~ver 2 )/8" Otis "XA" Sleeve 2 )/8"x2 ?/8" Buttress Czoss~ver ~ ~52.$?' Locater Sub .~ $~53.75' Baker h$oOel "O" Packer ~ 5~].7]' (55~,' Oil) w/lO.6' Seal Assy · 5554,7B' 2 7/8" x 2 ~/8" Butt:ess X-ove~ 2 ~/8" Otis "X" Ni~im S Mule. Shoe 0 5~97, 54' SHORT STRING ' A, 2 }/B" Otls X~ Eall Value ~ ~-D. 2 ~/8" Side Pocket C.L,M, · 2175.i6' C) 3~2~.2~' O) ~. 2 ~/8" Ctts "xA" Sleeve 0 4372.38' r. Baker 14odel A-~ ~al Packer G. 2 ~/8" Otis "XN" Ni¢~!e O NOTES: Minimum I.O. In 'XA' sleeves(S.875') HYDRIL to Buttress crossover between blast Joint: Shot Density D ZONE 53-0 $ 5a-8 Sd. 54-5 Sd. E ZONE 58-1 Sd. HEMLOCK PERFS: ' '... -d~' T. B.S. 5-81 · PERFO ~oterva! 6663-6876 68~6-6900 -6270-~310 "-5675-577Q - 5600-5~25 -5210-52~5, RA'TION RECCRD ' · ~ml0ck pe~cmt retainer $~z~o ~/ 200 s~s "~" ~/ additives ~zeo w/ 200 sxs "G" w/ a~dltlves ~B-i san0 open for Produc:lon ~zed for 5~-5 san0 33-B sand 53-0 sand 53zed for fi-6 sand ~ze~ for 50-3 sand ~3=7 s~nd isolation open 'for ~:o~uc~lon open.fo~ ~roductic~ oder for DroCuction eden for Production isolation o~en for production open (or ProOuctlon C-~ ,3nO oosn ~: =roductlcn · ~ C-5 s~nd open fo. :~oOucti~n a~28-a430 5=;~ fo~ isolat -- . ..... _ . .....: .~ ... WO KOVE SCHEMATIC WELL COMPLETED : 2/84 .... ONION OIL COMPANY OF CiI. II~ORNiA WELL A-gRD MONOPOD PLATFORM DESCRIPTION SUMMARY OF PROPOSAL . . 0 m Move in and rig up. Kill well. Nipple down tree, install and test BOPE. Recover existing dual completion and permanent packer at 5554'. Clean out to TD ~ 6480' Reperforate the C and D Zones. Run a single 2-7/8" completion. Rig down and move off, place well on production. Note: SBPH anticipated to Oe 2000 PSI STATE OF ALASKA ALAS,. ,, OIL AND GAS CONSERVATION ~)MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Union 0il Company of California 81-36 3. Address 8. APl Number P. 0. Box 6247 Anchorage, Alaska_ 99502 50_733-30062-01 4. Location of Well Conductor #16, 1625'N & 566'W of SE Corner, Section 4 T9N, R13W, SM.~ 5. Elevation in feet (indicate KB, DF, etc.) RT 101' MSL 6. Lease Designation and Serial No. ADL 18731 9. Unit or Lease Name Trading Bay State 10. Well Number TBS A-9 RD OTHER [] 11. Field and Pool Trading Bay State Hemlock, C D, & E Zones 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 [X] 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). ' 'PROCEDURE 1., Moved Rig #56 over TBS A-9 and rigged up. 2. Killed well, installed BPV, removed .tree, installed and tested BOPE to 3000 psi. 3. Pulled and recovered 2 7/8" compl, etion assembly. 4. Abandoned Hemlock perfs w/35 sxs cmt on top of cmt ret set @ 6550'. 5. Squeezed for isolation, opposite "C", "D", and "E" zones, as follows: 6264-6268 w/170 sxs 5590-5592 180 5339-5341 200 4999-5001 150 4615-4617 160 4428-4430' 160 6. Ran GR/CBL/CLL logs f/6463-2800 7. Perforated and squeezed f/4611-4613 w/167 sxs cmt. (Continued on page two) RECEIVED, r !AR 22 1984 Alaska 011 & Gas Cons. Cornrnlaalon Anchorage rtify ~oing - Date 03/23/84 is true and correct to the best of my knowledge. Tit~ District Drilling Supt.- 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 SUNDRY NOTICES AND REPORTS ON WELLS Page 2 8. Perforated the "C" "D" & "E" Zones as follows: 6270-6310 w/8 HPF 5805-5825 8 5675-5770 8 5600-5625 8 5425-5500 8 5210-5245 8 4555-4585- 8 4435-4475 8 9. Completed well as a dual 2 3/8" "C" & "D-E" completion with a Baker Perm Racker set at 5544' DIL. 10. Installed BRVs, removed BORE, installed & tested tree to 5000 psi. ll. Returned well to production. ? AWSk~ Oil & Gas Oons. OommWsio~ Anchorage sTATE OF ALASKA ~-h ~"-~ ~'"'~ ALASK, , OIL AND GAS CONSERVATION ~..)MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION · Drilling well [] 2. Name of operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 4. Location of Well at surface Workover operation [~ 7. Permit No. 81-36 ~" 8. APl Number //'~ 50- 733-20062-01 ~/~ 9. Unit or Lease Name Trading Bay State ANCHORAGE AK 99502 Conductor #16, 16.25' N. & 566' W. of S.E. Corner Section 4, T9N, R13W, S.H. 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. RT 101' MSL J ADL 18731 For the Month of. February ,1984 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced Operations ® 00:01 Hfs, 2/04/84 Released Crews ~ 24:00 Hfs, 2/29/84 ETD 6466' $ 2/29/84 13. Casing or liner run and quantities of cement, results of pressure tests Ran dual 2 3/8" comp assy w/ Baker "D" Pkr $ 5544' 10. Well No. TBS A-9 RD 11. Field and Pool Trading Bay Field Hemlock 14. Coring resume and brief description None RECEIVED ~" ' ,, 1984 Alaska Oil & Gas Cons. Commission Anchorage 15. Logs run and depth where run Ran CBL/GR/CLL logs f/ 6463-2800' 1 6. DST data, perfnratinn dat~ ~hnws of H2S, miscellaneous data Abandon Hemlock Perfs f/ 6876-6663' w/ 35 sxs cmt perf'd & Sqzo f/: f~ 6266-6268' w/ 170 sxs cmt ~ f/ 5590-5592' w/ 180 sxs cmt f/ 5339-5341' w/ 200 sxs cmt f/ 4999-5001' w/ 150 sxs cmt f/ 4615-4617' w/ 160 sxs cmt f/ 4428-4430' w/ 160 sxs cmt f/ 4611-4613' w/ 167 sxs cmt Perf'd for Proeuction f/ 6310-6270' w/ 8 HPF f/ 5500-5425' w/ 8 HPF f/ 5825-5805' w/ 8 HPF f'/ 5245-52~0' w/ 8 HPF f/ 5770-5675' w/ 8 HPF f/ 4585-4555' w/ 8 HPF f/ 5625-5600' w/ 8 HPF f/ 4475-4435' w/ 8 HPF 1-~i '~-her~y/l?~ify that the foregoing is true'and correct to the best of my knowledge. LI ~ £. :' . /t ~ DISTRICT DRLG SUPT 03/16/84 NOTE--I~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 Oil and G"as Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE Of ALASKA ;-., ALASK~-~IL AND GAS CONSERVATION ~ :MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COHPANY OF CALIFORNIA 81-36 8. APl Number 5o-7~-20062-01 3. Address PO BOX ~247 ANCHORAGE AK 99502 4. Location of Well Conductor #15, 1525'N & 555'W of SE corner, Section 4, TgN, Ri>W, 5. Elevation in feet (indicate KB, DF, etc.) RT 101' HSL 12. I 6 . Lease Designation and Serial No. ADL 187:~1 9. Unit or Lease Name TRADING BAY STATE 10. Well Number TBS A-9 RD 11. Field and Pool TRADING BAY FIELD HEHLOCK 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). PROCEDURE: 1. Hove Rig #55 over TBS A-9 and rig up. 2. Kill well, install BPV, remove tree, install and test BORE. Rull and recover 2 7/8" completion assembly. 4. Abandon Hemlock perfs thru retainer at +5550'. 5. Squeeze for isolation as required, oppos-ite "C", "D", and "E" zones. 5. Rerforate and test "C" "D" and "E" zones as directed 7. Complete well as a dual 2 3/8" "C" and "D-E" completion. 8. Install BRV's, remove BORE, install and test tree. Return well to production. RECEIVED / bs txe~t W.o~k Repo~te& JUN2 !983 o~ ~o~ Ho, ~ Alas~ 0il & Gas Cons. Commission ~chorage 14. I h certify that th~e~ is true and correct to the best of my knowledge. / S,~nod~ /¢ (~~ J~ /t,~ District Drlg Superintendent Dat. T~/e be I ow for e ommission use .... ~itions of Approval, if any: 6115/83 Approved Copy Returned BY 10NNIE C. SMITll 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 CO,...,vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator UNION 0IL COHPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well 1625'N & 566'W of SE corner, Sec. 4, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) RT 101' MSL 12. Check Appropriate Box To Indicate Nature of Notice, RepOrt, or Other Data 8. APl r o, 9. Unit or Lease Name TRADING BAY STATE 10. Well Number TBS A-9 RD 11. Field and Pool [ 6. LeaseADLDesignation18731a_nd Serial No. ~~ BAY 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 coordinates of the TBS A-9 RD well should be corrected as follows: Location of well at surface: 1625'N & 566'W of SE corner, Sec. 4, TgN, R13W, SM. At Top Producing Interval: 1484'N & 2617'W of SE corner, Sec. 4, TgN, R13W, SM. At Total Depth: 1490'N & 2772'W of SE corner, Sec. 4, TgN, R13W, SM. I ECEIVE DEC 0 2 982 Alaska Oil & Gas Cons Anchora~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~_~___ ..~, 0~ / A~,~ Title DiStrict Drlg Superintendentoate / The space b~lJi)w for Commission use '~ Conditions of Approval, if any: 11/24/82 Approved by By Order of COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions' in Triplicate and "Subsequent Reports" in Duplicate ..... Document Transmittal ;;' ~* ~'* i.' ~ ~,,. !.; ~-.. Union Oil Company of California ~' ,~. ~. ~-* ~. ~, ~., DATE SUBMITTED ':.:::.'i, ,: ~-26-82 Paoe 1 of; ACCOUNTING MONTH FROM !, ,~. r' 1 ;, ~ I. ~,~ f~l ':-- AT ..... !'.'.'.> 47 + :z .'C';:, ~. -.'.:..,~,,~ bt./ "tQ5ft? .-;, ;,.. ..... ., .. ~ -,, ...,.. TELEPHONE NO. ?nci,ora!~e, L1 aska TRANSMITTING THE FOLLOWING: · .'I) F ' ' ,'/.-' ;~ :, ::: Tan,:;ential Directional survey -T~. 2" and' 5" DIL 5" FDC Rad. of Curv. Dir. Survey- Tang. Ave. Anlge Dir. Survey Rad. of Curv. Olr. 5urveY Diqitized. [l~c. lo~ ':ape #61631 FORM 1-2M02 (REV. ! 1-'72) PRINTED IN U.S.A. Mr, Robert C. Warthen Union Oil Company of California P. O. Box 6247 .Anchorage, Alaska 99502 April 22, 1982 Re: Missing Information - Completed Wells Dear Bob: We wish to bring to your attention that the below-indicated material on the following Union Oil Company wells has not yet been received by the Alaska 0il and Gas Conservation Commission: Well Granite Pt. ~33-14RD ..C0mp!e_t ion Date 3/6/Sl Missing Material -DIL/SP & CBL/VDL Elec. Logs. Trading-Bay Unit ~D-9RD 3/2/82 -Digitized E. Log Tape Trading Bay Unit ~D-16RD Trading Bay Unit ~D-17RD 6/22/81 -Directional Survey -Elec. Logs -Directional Survey Trading Bay Unit #K-3ED 5/22/81 Trading Bay.~.St. #A-PRD ~' 5/6/81 -well History -Directional Survey -Digitized E. Log Tape Trading Bay St. tA-17RD Cannery Loop Unit t3 Kenai Unit #34-32 7/3/81 9/13/81 1/18/82 -Digitized E. Log .Tape -Digitized E. Log Tape -Digitized E. Log Tape -Certified Survey Plat -Directional Survey -DST or Prod. Test Reports Trail Ridge Unit #1 12/13/80 -Certified Survey Plat Please submit the above material at your earliest convenience since you are now in violation of. Title 20, Chapter 25 of the Alaska Admin- istrative Code. Very t~.,uly y~ours, William Van Alen Petroleum Geologist WVA:v~I J. R. Callender District Drilling Superintendent Alaska District Union Oil and Gas Di,;~)n: Western Region Union Oil Company of L;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union March 29, 1982 Chat Chatterton AK O&G Conservation Comm. 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Please note the addition of the 9 5/8" casing detail attached below the 7" detail of the TBS A-9 RD well history. This is to replace just this one page previously sent earlier as part of the history. If you have any questions, please contact Donna Melton at the above mentioned number. Sincerely, O~i~ R Callender ' drm CC: USGS Dave Courtis Bob Culver Harold Piland Dick Evenson Marathon Oil Co. John Underhill APR 0 1 J982 Naska Oil & Gas Cons. UillOIt OIL CD'?AICF OF CALIFOF~,iIA WELL RECORD SI2k-T D PAGE ih, -" LEASE ~r~~ ~a¥ ~LL NO, ~-9 ~ FIELD Tradinq Baxz . .. DATE Frcm T6 7020.20 7018.32 ETD DETAILS OF OPERATIOHS,_.DESCRIPTIOI.!S & RESULTS 7,", Casing. Detail 1.88 Description Howco 7" Float Shoe 701'8.'32 6978.56 39.76 1 6978.56 6976..'.86 ~ 1.70 ! 6976.86 5887.23 · 1089.63 26 7" 29# P-li0 Howco 7" Float Collar 7" 29# P-110 5887.23 .,-5866.95 5866.95 68.61 ,20.28 1 57"98.34 145 7" 29# N-80 Pup Jt. 7" 29# N-80 68.61 37J20 ' 31;41 1 Cut off 7" 29# N-80 37.20 -0- Landed below zero - - ' CASING & TUBING RECORD SIZE ~SPTH, I WE! :/~ GRADE REMARKS -3 3/84 1082' 61# 3-55 Cmt'd w/800 sxs. Cl. "G" w/CFR-2 & 400 sxs. C1 "G" neat. 9 5/8" 253' 43.5# N-80 Cmt'd in 2 stages. 1st stage w/550 sxs. Cl. "G" w/CFR-2 3225' 40# J-55 ? and 2nd stage thru D.V. collar @ 4384' w/1350 sxs. Cl. "G" w 5483' 40# N-80 CFR-2. The top 253' of pipe is uncemented and held together 6736' 43.5# N-80 w/ a Tri-State csg. patch @ 253'. 9 5/8" .casing. Detail From T__q Length JTS 1995.00 1993.40 1.60 1993.40 1947.70 45.70 1947.70 1946.14 1,56 1946.14 38.0 1908.14. 38. O0 0 38. O0 1 - , Description .. Float Shoe 9 5/8" 47# N-80 Buttress Float Collar 9 5/8" 47# N-80 BUttress Landed below zero RECEIVED, .,.APR 0 1 1982 STATE OF ALASKA ALASK~, OIL AND GAS CONSERVATION Cu~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. Union Oil Company of California 67-14 3. Address 8. APl Number P. 0. Box 6247, Anchoraqe' Alaska 99502 50-733-70062 OTHER [] 4. Location of Well 1625' N & 9566' W of SE Corner, Sec. 4, TgN, R13W, 9. Unit or Lease Name Trading Bay State 10. Well Number ~-9RD 11. Field and Pool Trading Bay-Heml ock 5. Elevation in feet (indicate KB, DF, etc.) l Ol' RT above MSL 6. Lease Designation and Serial No. ADL-18731 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 X~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull 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 reperforated September 23, 1981. 6663'-93' 6645'.63' I ECEiVED NOV 1 0 ]98] Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby cer~ JiJ3~the foregoing is true and correct to the best of my knowledge. C. H. Case Title District Enqineer Signed The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by. COMMISSIQNER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ~ ALASKA ,alL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Union Oil ComPany of California 67-14 3. Address 8. APl Number P. O. Box 6247, Anchorage, Alaska 99502 5o-733-70062 4. Location of Well 1625' N & 9566' W.of SE Corner, Sec. 4, T9N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 101' RT above MSL I 6 . Lease Designation and Serial No. APL-18731 12. 9.. Unit or Lease Name Trading Bay State 10. Well Number A-9RD 11. Field and Pool Trading Bay-Hemlock 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). It is proposed to reperforate the following intervals. 6663'-93' 6705'-55' 6826'-76' Subsequent Work Rep-ortecl on Form tqo. RECeiVED NOV 1 Alaska 0il & Gas Cons. Commission Anchorage 14. I her~he foregoing is true and correct to the best of my knowledge. Signed~~%''''~ Title District Engineer The space below~' i-j,. Case TOr ~,ommlsslon use Date 11/5/81 Conditionsof Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Robert T. Anderson District Land Manager Union Oil and Gas ,ison: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union October 16, 1981 Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 STATE OF ALASKA 1981 Permits to Dr{ll Correction of Bonding Information Dear Mr. Hamilton: It has been brought to my attention that we have been carrying incorrect bonding information on all Union operated Permits to Drill submitted to the Alaska Oil & Gas Conservation Commission since January 1, 1981. For each of the below listed wells, Item No. 12 on the Permit to Drill (Form 10-401) should be changed from United Pacific Insurance Company (B-55372) in the amount of ~100,000.00 to NationaI Fire Insurance Company of Hartford (B-5534278) in the amount of ~200,000.00. WELLS PERMITED DATED PERMITED API NUMBER DATED APPROVED 3/17/81 50-733-20062'01 3/24/81 CLU #3 4/20/81 50-133-20340 4/28/81 TBS A-17.-Rd. 5/12/81 50-733-20135~01 5/15/81 KDU #7 6/26/81 50-133-20341 7/27/81 KDU #8 6/26/81 50-133-20342 9/17/81 WD #1 7/14/81 Pending Pending KBU #31-7 10/8/81 Pending Pending KU #34-32 10/8/81 Pending Pending Tungak Creek #1 10/14/81 Pending ~ ~ ~ ~ ~ %~ ~ ~Pending "~. ~. ..,. < !;' ',... ~' Alaska 0il & Gas Cons. Commlsslon .".. Anchorage 1981 Permits to Drill Correction of Bonding Information -2- October 16, 1981 We would appreciate your reflecting these corrections on your copies of the subject Permits and we will do the same on ours. We apologize for the oversite and any inconvenience this has caused. Ail future Permits submitted for your approval will have the current bonding information on them. Very Truly yours, Robert T. Anderson sk cc: Ann Lannin-LA Office Jim Callender RECEIVED OCT 2 0 1981 Alaska Oil & Gas Cons. Commission Anchorage " ~ ~'--"'~, STATE OF ALASKA ALASKA-!:, ~ANDGASCONSERVATION C(2, _.~ISSION WELL COMPLETIO' iil OR'RECOMPLETIONREPORT AND LOG 1. StCtus of Well "' Classification of Service Well · .. OIL [] GAS~] SUSPENDED E]" i .ABANDbNED [] SERVICE"[] 2. Name of Operator , 7. Permit Number UNZON 0IL COMPANY OF CALIFORNIA ~i~- 3. Address 8. APl 909 W. 9TH AVE.. ANCHORAGE. AK. 5o-733~ 4. Location of wel~ atsurface 1 625'N & t)566'W of S.E. Cor. Sec 4, T9N, R13 9. unit or Lease Name W, S.M. Trading Bay State AtlopProducing~nterva~ 1600"N & 2550' W of S.E. Cor. Sec 4 T9N, R13 lO. We~Number W, S.M. TRg A-qRD At Total Depth 1530' N & 2700'W' 'of S.E. C0r. Sec 4 T9N, R13W, 11. Field and Pool S.Mo Trading Bay - Hemlock ~5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 101 ' Rt above MS!_ ADL -18731 12. Date Spudded4_l 0-81 13. Date T.D. Reached 4- 29-8l 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns5-11-81 621feet MSL 1 · 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7032' MD (¢HR$TV0 385 MD YES'i] NO [] 313 feetMDI --- 22. Type Electric or Other Logs Run CC, D LI_-SP-GR: FDC-CNL-GR. BHC-Sonic-GR; CBL-VDL-GR. Go Int. Gr. 23. CASING, LINER AND C'EMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 47# N-80 Surface 1995" 12 1/2" 650 SaC:ks 7" 29# 80to5887 *Surface 7020' 8 1/2" 100 sacks *P-110-588i'-7020' Milled llindow in 13 3/8" ,;s.g 380'-435,' K0P .a 385' 24. Perforations open to Production (M.D+TVD of Top and Bottom and 25. TUBING R ECOR D .. in.terval, sizeand number).4 HPF '- - SIZE DEPTH SET (MD) PACKER SET (MD) - 6826'-6876' 2 7/8" 661g 66f~g 6730' -6755' · · , 6663 '-6693' 2'6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED . ".. "'": ', '- ' 6896'-6900' 200' sxs CL-"G" · 6638'-6642' 200 sxs CL "G" 682~;'-6876' 9f),000¢¢ Sand · · .:: . ' " . - "-'' ' '" '6~30'-6755' 90,flOO~ Sand 27. ' ':' ' ' PR(~DucTION TEsT 6663'-6693" 95,000# Sand Date First Production I Method of Operation (Flowing, gas lift, etc.) :'-'5Z1,2:81", .. :'. I? ,.. '1 Gas'Li~ft. -.. .` .. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF ' WATER-BBL CHOKE SIZE IGAS'OILRATIO 5-21,81 16 TEST PERIOD, I~.. 21 109 254 35/64I 5125 , · FieTM Tubing Casing P~essure · CALCUI_.ATED ', Oil:DEL GAS:MCF WATER-BBL OIL GRAVITY-APl (corr) Press.~i 150" .973 -24-HOURRATE? '"32 ~'' .i64 ~ ' 38i 28.9 28. ' . L. :~ " ~ ' ;- ' CORE DATA ' · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Alaska Oil & Gas Cons. Comrn/ssiori , ..... '" ., ..~., : . ~,~--..:. :. , ,:-, · . Anchorage submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERSI ~':')~ :.,,'~ ~','i :'i.',,i', ~ ;! :;'i :: NAME Include interval tested, pressure data, all fluids recovered and gravity; MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 'I'/H ernl ock 6628 6129 · 31. LIST OF ATTACHMENTS , 32. ' I hereby c~ that the foregoing is true and correct to the best of my knowledge . - .,. ./ ,~' Signed../'" .~ Z /-"l.~_~Title DIST DRLG SUPT Date 8/1 3/81 INSTRUCTIONS GeneraI' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this w.dl is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for.only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". TradincL--Bay State Trading Bay ©,I..' CO. ',...3;- .... Vq ELI_ I .~_COP, ID V/EI,L NO A-9RD :,OCiTlON_Conductor #16 1625'S & 566'E of SE corner of Sec. 4, T9N, 'R13W,_ S.M. S I-I t7 :-"T A PAGf.' SPUD DATE 6-4-81 CO~,{ t Ib~C lOlt Parker TYPE U?.IIT 860 Oilwell I' COMP. 1)ATE _~-5-81_ ...... ____ RIG NO. 56 ___ -~v":MIT NO. 67-14 SERIAL ...... ' 'C 112~ F.D. 7032 MD ~"-...w.'r" 6467' II, r~. TO ?,ILI.,,'~ DEVIATION (B.I[.L.) 219V' at S86° 28'W R,?', U.[5 D COMPANY ENGINEER Watson-~v.~e V/EIGiCF THREAD .... GRADE__ 61~ Buttress J--55 47# SIZE _'9 5/8't 7" I 29# 2 7/8't 6.4# . Buttress Buttress Buttress N-80 P-110 N-80 N-80 CASING & TUBING 1082 3/8" Window f/380''460' 1995 'l. Cmt'.d ...w/650 SX "G" w/additives tot°661870205887.,' Pkr.Ont'd--w/10006608 SXS ".G" w/additives .---~= __ PERFORATING RECORD _P.Ay~ L -ILtEiU~kL E,%D. RE~qO1L J P H _E_S E ICC_C_Q_I t 12 LT LO_; [ ., 5-6-81 6826-6876 .6886 . ~uction J~rP~ Ho~] ~k znn~ 5-10-81 ~730-6755' 6886 '., Pr~uction Frac~P~ H~~k Zone , ., ~-9-8~_ ~63-6693 6886 "' ~r~uc~0n. Frac-P~ H~ock zone -- ;-3-81 . 6~38-42 6886 . '" " Isolation & ~z'd w/200 S~ "G" w/additives . _-- i-3-81 6896-6900' 6886 Isola~on &' ~z'd w/2'00 SXS "G" w/addi%ives . . ,. . . . . ~-- ~ _ ~ '. _ ~,~ .... ~--~_~t ........ ~ ~ .... INITIAL PRODUCTION DIkTE ',"IIi'TEA't'AL N_ET,OIL1 CIST, GRg.~. C.P. T_..~., ] CHOk'__E. i~J__Ce_~-__ GO_QJ3, "l'e ,. ~.F.~,I"~"~,C,~ - -21-81 . _ 32, ,t 92% 28:9_. .35/64 164 , , , ' · .. , , . , W E_L_L__ H_EAD_A_ _SiE/4 D_kY, · TYPE: CASING HEAD: Shaffer Model .~D, 12" - 900 w/2" 'Outlet§ 13 3/8" SOW CASING HANGER: CIW 12" x 7" CASING SPOOL: Cameron 12" 3000 psi x 12" 3000 psi' ' TUBING HEAD:_ ClW'12" 30'00 psi x'10" 5000 p~i CIW 2 7/8" Single TUBING IIANGER: 2 7/8" EUE TUBING tIEAD .TOP' 2 9/16." MASTER VALVES: CItR!STMAS 'FRI,',E TOP CONN.:__=2_7/8'' MAR 1 9']982 AlasKa Oil & Gas Cons. Commisaion Anchorage ! I Ui'lIOl.l OIL Cg'?A~IY [Y CALIFORHIA WELL RECORD S);IEET D PA~E ih, LE~SE Trading Bay St. DATE Frc~ 7020.20 70i8.'32 6978.56 6976.86 5887.23 5866.95 68.61 37.20 7018.32 6978.56 ~976J86 5887.23 '5866.95 68.61 '37220 --0-- ~ · ~'ELL HO, ~-9 ~ FIELD Tradinq .Bay ,DETAILS OF OPERA_TIOI.tS, DESCRIP, TIOI!S & RESULTS. 7". ,Casing Detail 1.88 39.'76 1.70 1089.63 26 120.28 57~8.34 145 1 31~ 41 1 ETD Landed below zero .: Description_ Howco 7" Float Shoe 7" 29~ P-li0 Howco 7" Float Collar 7" 29# P-110 7" 299 N-80 Pup Jr. 7" 29~ N-80 Cut off 7" 299 N-80' ur. iIOr.l OIL CgPArlY OF CALIFOR~.iIA EkL ~E¢ORD SKEET D P^aE L~S[ Trading Bay State DATE ETD ~'ELL [~0, x-9 ~ FIELD Trading Bay DETAILS OF OPERATIOI'tS, DESCRIPTIOHS & RESULTS , Tubing Detail From 6618 51 6618.08 6608.00 6607.02 6575.96 6569.35 5858.13 5851.52 4919.35 4912.74. 3601.32 3594.71 2001.87 1995.26 315.59 313.27 34.72 33.72 · To '6618.08 '66o8;oo , 6607.02 , 6575.96 6569.35 5858. i3 4919.35 4912.74 3601.32 3594.71 2001.87 i995.26 · 315.59 , ~.7~ 33.72 -0- .43 10.08 JTS .98 :31.06 1 i 6.61 711.22 23 ,. . 6.61 932.17 30 6.61 1311.42 42 6.61 1592.84 51 6.61 1679.67 54 2.32 313.27 9 · 1.00 · Tubing landed below zero. Description 2 7/8" Mule Shoe Baker 2 7/8" MOdel D Pkr · w/5' Seal Assby. Baker 2 7/8 Locator Sub. 2 7/8" 6.4# N-80 Butt. Tbg. Camco 2 7/8" K~MG 2 7/8" 6.49 N-80 Butt. Tbg. Camco 2 7/8" K~{G 2 7/8 6.49 N-80 Butt. Tbg. Camco 2 7/8" KBMG 2 7/8" .6.4~ N-80 Butt.' .~bg. ,. Camco 2 7/8" KBMG 2 7/8" 6.4# N-80 Butt. Tbg. Camco 2 7/8" KBMG 2 7/8" 6.49 N-80 Butt. Tbg Otis 2 7/8" Ball Valve 2 7/8" 6.4# N-80 Butt. Cameron Tbg. Hanger 71 I II I I ' A-9RD Otis "XEL" Ball 'Valve 313' knt. Ret. 251 ' .. Cmt. Ret..63( Window 13 3/8 380"'460' 5/8 1995' m Baker Model "D" 6371' -'9 5/8" 6736' Camco~ 1995 ~a~co~.3595' · bmcoKBMG 4913' ~coK~ 5858' I Camco KBMG 6569' 12BakerLocator. Sub 6576' Baker~Model "D,I Pkr. 6608' 7/8 ~le Shoe 6619' Hemlock Perfs ' 6663'-6693' -- 6730'-6755.' 6826'-6876' 7"C. 7020' Well Sch~atic · TradingBay Field A-9RD None 6-5-81 UNION OIL COMPANY OF CALI,r-OJINIA DAILY COST. ACC COST: AFE AMT. U'T FL, I- 9'9' $ 18,913 $ 128,246 $2,360,000 LEASE ADL 18731 UrlIOH OIL CC '?AI',IY CF CALIFOP ,iIA WELL RECORD SHEET D PAGE f,b, ...l . ELL NO, TBS A-9RD FIELD TRADING BAY FIELD . DATE 1 3/24/8i DAILY COST: ACC COST: AFE AMT: 2 3/~5/81 DAIL~ COST: ACC COST: AFE AMT: 3 3/26/81 DAILY COST: ACC COST: AFE AMT: 4 3/27/81 DAILY COST: ACC COST: AFE AMT: 5 3/28/81 DAILY COST: ACC COST: AFE AMT: ETD 6896' TD 6650' ETD (Junk) 13 3/8" C. 1082' 9 5/8" C. 6736' FIW · $ 8,785 $ 8,785 $ 2,360,000 6896' TD 6650' ETD (JUNKI 13 3/8" C. 1082' 9 5/8" C. 6736' FIW $ 24,125 $ 32,910 $2,360,000 6896' TD 6650' ETD (JUNK) 13 3/8" C. 1082' 9 5/8" C. 6736' FIW $ 29,725 $ 62,635 $ 2,360,000 6896' TD 604' ETD (Ret) 13 3/8" C. 1082 9 5/8" C. 6736' 64 PCF 42 SEC $ 46,698 $ 109,333 $2,360,000 6896' TD 604' ETD (Ret) 13 3/8" C. 1082' 9 5/8" C. 6736' 64 PCF 44 SEC $ 18,913 $ 128,246 $2,360,000 DETAILS OF OPEP~TIOIIS, DESCRIPTI~.[S & RESULTS Commence~ operations 12:00 HRS 3-24-81. ~oved RIG F/' TBS A-17. Killed Wet1, installed BPV, removed tree installed & tested BOPS. NOW: Prep. to pul! tubing. Pulled Baker Dual A-5 PRK loose w/ 45M# over tbg. wt. CIRC down S.S. taking returns in annulus. CIRC '. down L.S. & it plugged. R.I.L.S. w/ wire line & Baker Shiftifig tool. Coul4n't work below 186' due to wax. R.I..w/ wax cutter. Couldn't work below 1£ Pulled tbg. & layed.down ball valve. S.S. still givimg up was lift gas. R.I.H .& perf'd S.S. @ +'6310'. Rev. CIRC S.S. giving prod. oil r--eturns unitl ~lean. NOW: Pulling & laying down 2 7/8" c~ual tbg. Pulled & layed down dual 2 7/8" Comp. Assy. R.I.H. .W/ 8 1/2" Bit & 9 5/8" Csg. Scraper to PKR @ 6371' CIRC well W/ F.I.W. - Received oil cut returns back' to surface. CI.RC on choke & well still wouldn't clean up. NOW: Mixing Gel Mun. Mixed gel mud. POOH~ Set & sqz'd Hemlock perfs for abandonment thru cmt ret set-@ 6300' w/ 200 s.xs to a final pressure of 5100 psi. Set & sqz'd "A" zone perfs for abandon- ment thru cmt ret set @ 2510' w/ 500 sxs to a final pressure of 3100 psi. Set cmt ret @ 604'. Cut 9 5/8" cs9 @ 258'. Raised BOP stack & removed "DCB" spool & 9 5/8" slips. Installed 9 5/8" rams in btm single gate. Pulled 9 5/8" f/258' w/ spear. Removed 12" 3000 x 12" 3000 psi csg spool. RIH w/ 12 1/4" x ll 3/4" washover shoe & washed over 9 5/8" csg to 291'. LEASE ADL 18731 DATE 6 3/29/81 DAILY COST. ACC COST- AFE AMT: 7 3/30/8~ ETD 6896' TD 604' ETD (Ret) 13 3/8" C. 1082' 9 5/8" C. 6736' 64 PCF 44 SEC $ 23,925 $ 152,171 $2,360,000 6896' TD 604' ETD (Ret) - 13 3/8" C. 1082' 9 5/8" C. 6736'~ 64 PCF 53 SEC DAILY COST:. $ ~3,765 ACC COST: $ -. 175,936 ' AFE AMT- 8 3/31/8l DA I LY CO'ST' - ACC COST: AFE AMT: S EE'F D U['I[OI.I OILOF CALIFORNIA WELL RECOP _ , ELLNO, TBSA-9RD FIELD TRADING BAY FIELD 9 4/1/8l DAILY COST: $ ACC COST- $ AFE AMT' $ lO 4/2/81 'Washed over 9 5/8" csg 291' to 310'. Trip for shoe #2. Washed over 9 5/8" csg f/ 310' to 325'. POOH. Cut 9 5/8" csg f/ 318'. Pulled 9 5/8" csg f/ 318'. RIH & washed over 9 5/8" f/ 325' to 327'. Trip for shoe #4. Washed over 9 5/8" f/ 327' to 329'. NOW' Washing over 9 5/8" csg @ 329'. DAILY CO~T: $ ACC COST-- $ AFE AMT- $. 2 $ 2'360,000 Washed over 9 5/8" csg f/ 329' to 359'. Trip for shoe #5. Washed over 9 5/8" csg f/ 359' to 416'. POOH. RIH w/ cutter & attempt to cut 9 5/8" @ 410'. Cutter would not set.. POOH. Rec 4.75' stuL of 9 5/8"'csg. Cut &.pulled 9 5/8" csg f/ 400'. RIH & washed over 9 5/8" f/ 416' to 428'..i. .o , :-. NOW.:- Washing' over 9 5/8" icsg @ 428'. -.. ' TD ' ETD (Ret) 3 3/8" C. 1082' 5/8" C. 6736' PCF 49 SEC '23~617 199,553 2,360,0O0 Washed over 9 5/8" csg f/ 428' to 430'. Trip fo shoe #7. 'Washed over 9 5/8" csg f/ 430' to 444' Trip for shoe #8. Washed over 9 5/8" csg f/ 444 to 464'. Trip for shoe #9. Washed over 9 5/8" csg f/ 4621' to 465'. NOW: WaShing .over 9 5/8".csg @ 465'. .896' TD ' ETD (Ret) 3 3/8" C. 1082' I 5/8" C. 6736' ;4 PCF 49 SEC 23,948 223,501 ,360,000 896~' TD 04' ETD (Ret) 3 3/8" C. 1082' 5/8" C. 6736' 61 PCF 54 SEC 31,49'5 254,996 360,000 Washed over 9 5/8" csg f/ 465' to 471'. Cut & pulled 9 5/8" csg f/ 467'. RIH w/ shoe #10. Wash'ed over 9 5/8" csg f/ 471' to 476'. Trip for shoe #11. Washed over 9 5/8" f/ 476' to 487'. Stuck WO shoe @ 487'. Worked free .in 1 hr. POOH & Rec +_20' stuc of 9 5/8" jammed' in thc · Wash pipe. ' . NOW: RIH w/ shoe #12. RIH w/ shoe #12. Tagged up @ 473'. Milled f/ 473' to 483'. Trip for shoe #13. Milled f/ 483' to 487' Washed over 9 5/8" f/ 487' to 497' POOH. Rec +18' of 9 5/8" in wash pipe. (Note' T~e piece of 9 5-/8' recovered'on 4/1/81 had a pin looking down & the piece, rec this trip was pin up - collar st.ill in · ' hole). RIH w/ shoe #14. .Washed over 9 5/8" csg f/ --497'.. to 505'. Trip for shoe #15. Washed over 9 5/E csg f/ 505'" to 529'' Trip for shoe #16. Washed ove 9 5/8" csg f/ 529' to 537'. ' NOW- Washing over 9 5/8" csg @'537'. $ EET D U['IIOI.I OIL CCI'?A ,IY OF CALIFOP ,iIA PAGE i~]O, ---3 LEASE ADL 18731 WELL RECORD $. ELL NO, TBS A-9RD ,, FIELD TRADING BAY FIELD , .. DATE ll 4/3/81 DAILY COST: ACC COST: AFE AMT: 12 4/4/81 DAILY cOsT: ACC COST: AFEAMT: 13 4/5/81 DAILY COST: ACC COST: AFE AMT: 14 4/6/81 DAILY' COST: ACC COST: AFE AMT: 15 4/7/81 DAILY' COST: $ ACC COST: $ AFE AMT: $ ETD 6896' TD 405' ETD (Cmt) 20" D. 228' 13 3/8" C. 1082' 64 PCF 53 SEC $ 24,189 $ 279,185 $2,360,000 6896' TD 228' ETD (Cmt) 20" D. 228' 13 3/8" C. 1082' 64 PCF 40 SEC $ 117,583 $ 396,768 .$2,360,000 6896' TD 175' ETD (Cmt) 20" D. 228' 13 3/8" C. 1082' 64 PCF 46 SEC $ 32,127 $ 428,895 $2,360,000 6896' ID 470' ETD (RET) 20" D. 228' 13 3/8" C. 1082' 64 PCF 284 SEC $ "22,462 $ 451,357 $ 2,36O,000 6896' TD 470' ETD (Ret) 20" D. 228' 13 3/8" C. 1082' 64 PCF 28O SEC 28,62'1 47-9,978 2,360,000 DETAIL W~shed over 9 5/8" csg f/ 537' to 554'. POOH. Recovered a piece of 13 3/8" csg 8' long in wash pipe plus sand, gravel & coal. RIH w/ 12 1/8" IB - tagged up @ 492'. POOH. IB indicated fill @492' RIH w/ 8 1/2" bit. ROT off top @ 492' ~/o pump & RIH to.553'. CO to 560'. POOH. RIH w/ · 9 5/8" spear. Could not engauge 9 5/8" cs~t @ 492'. POOH. Ran CCL log f/ 500' to surface Ran & set Howco 13 3/8" cmt ret @470'. Had communication around ret. POOH. RIH w/ 13 3/8" RTTS. Tested 13 3/8" 'above 215' to 1500 psi. RIH. Could not set RTTS below 460'. Set @ 458' & broke. down formation under' tool w/ 100 psi & 30 CFM. Reset RTTS @ 341'& sqz'd below tool w/ 300 sxs CL "G" w/' 3% salt. CIP 17:50 hrs 4/3/81. Held sqZ in place 4 hrs. . 'WOC POOH. RIH w/ 12 1/4" bit & 9 5/8" scrpr & tagged cmt @ 405'. POOH. Perf'd 13 3/8". @ 390'. Set baker full bore @ 280' (would not set between 290' & 320'). Sqz'd below tool w/ 250 sxs w/ 3% salt. CIP @ 17:00 hrs 4/4/81. Held sqz in place 4 hrs. WOC. Set full bore @ 153' & sqz'd holes @ 228' w/ 250 sxs w/ 3% salt. CIP @ 01:30 hrs 4/5/81. Held sqz in place 4 hrs. POOH. NOW: WOC. WOC. RIH w/ 12 1/4" bit & CO cement f/ 202' to ret @ 470'. Clean pits & build mud to cut sectior Trip for section mill. Cut section in 13 3/8" csg f/ 380' to 382'. NOW: Trip fo~ new cutters. .. .. .. .. RIH w/ mill #2. Cut section in 13 3/8" csg f/ 382' to 390'. Trip for mill #3. Cut section in 13 3/8" csg f/ 390' to 395'. Trip for mill #4. Cut section in 13 3/8" csg f/ 395' to 396'. Trip for ~ill #5. Cut section in 13 3/8" csg f/ 396' to 398'. NOW: Cutting'section @. 398'. . · · S {EEI D U['ilOl.! OILLF CALIFOPJ.iIA PAGE i'b, '" 4 LEASE ADL 18731 DATE 16 4/8/81 DAILY'COST' ACC COST' AFE AMT- 17 4/9/81 DAILY'COST' ACC COST- AFE AMT- 18 4/10/8' DAILY COST: ACC COST: AFE AMT: 19 4/11/81 DAILY COST: ACC COST: AFE AMT: 20 4/12/81 DAILY COST' ACC COST- AFE AMT: ETD 6896' TD 470' ETD (Ret) 20" D. 228' 13 3/8" C. 1082 64 PCF 195 SEC $ 26 ,'029 $ 506,007 $2~360,000 6896' TD 200' ETD (Cmt) 20" D. 228' 13 3/8" Window f 64 PCF 180 SEC $ 3~,613 $ 544,620 $2,360,000 630'/312' 20" D. 228' 13.3/8" Window 66 PCF 72 SEC $ 19,314 $ 563,934 $2,360,000 630'/325' 20" D. 228' 13 3/8" Window 66 PCF 71 SEC $ 19,750 $ 583,684 $2,360,000 630'/245' 20." D. 228' 13 3/8" Window 66 PCF 63 SEC $ 23,350 $ 607,034 $2,360,000 RECORD $- ELL HO, TBS A-9RD -. FIELD TRADING BAY FIELD DETAILS _OF DPERATIOHS, DESCRIPTIO[tS .& RESULTS ...... Cut section in 13 3/8" csg f/ 398' to 406'. Trip for mill #6. Cut section in 13 3/8" c.sg f/ 406' to 420' Trip for mill #7. Cut sect in 13 3/8". csg ~/ 420' to 435'. NOW' Cutting section @ 435'. 380' -460' Trip for mill #8. Cut section in 13 3/8" csg f/ 435' to 450'. Trip for mill #9 Cut secti in 13 3/8" csg f/ 450' to 460'. P~OH. RIH w/, OEDP. Equ. al ized kick off plug f/ 470' to 200 sxs "G" w/ 10% sand & 3% salt. POOH. NOW' WOC. . · · · F/380'-460' WOC. F/380'-460' WOC & clean out to 326'. F/380'-460' WOC R.I.H. W/ 12 l/4" bit & polish off kick off plug to 385'. Single shot Gyro @ 367' CIRC & cRnd mud. Trip for Dyna-drill. Orient D.D. 170Vleft of H.S. w/ single shot Gyro. Dyna-drilled 12 1/4" hole f/385' to 426' Trip for follow-up assy. Directionally ~rill¢ 12 1/4" hole f/ 426' to 617' taking gyro surw every 60' Trip for Dyna-drill. Oriented D.E 300 left ~f H.S. & Dyna-drilled 12 1/4" hole f/ 617' to 630'. NOW' Dyna-drilling @ 630'. LEASE ADL 18731 DATE · 21 4/13/81 DAILY COST: ACC COST' AFE AMT: 22 4/14/81 DAILY COST' ACC COST' AFE AMT' 23 4/15/81 DAILY COST'' ACC COST' AFE AMT' 24 4/16/81 DAILY COST' ACC COST: AFE AMT: 25 4/17/81 DAILY COST: ACC COST: AFE AMT: OIL C(I'?A .N OF CALIFOR . IA WELL RECORD ELL NO, TBS A-9RD FIELD S EET D PAGE i'b, ---5 · .,,, .. TRADING BAY FIELD ETD 1349'/719' 16" D. 228' 13 3/8" Window F/: 72 PCF 38 SEC $ 35,192 $ 642,226 $2,360,000 1644'/295-' '16" D. 228' 13 3/8" Window f/ 73 PCF 46' SEC $ 46.,764 $ 688,990 $ 2,360,000 1995'/351'' 16" D. 228' 13 3/8" Windown 72 PCF 42 SEC $ 32,199 $ 721,189 $ 2,360,O00 1995'/1939' 16" D. 228' 13 3/8" Window'f 9 5/8" C. 1995' 71 PCF 43 SEC $ 38,626 $ 759,815 $2,360,000 , .D~TAIL. S. OF OPER~TI_OHS, DESCRIPTIO~.~S & RESUL.TS. Dyne-drilled 12 1/4" Hole F/ 630' to 690'. P.O.O.H. RIH W/ Bit #2RR on BHA #4. Directionally 180'-46 drilled 12 1/4" 'Hole F/ 690'to 947' & hit possible obstructi'on. (Closest known well is 20' away.) P.O.O.H. Bit had no signs of running on iron. RIH W/ Bit #4 on BHA #5. Directionally drilled 12 1/4' hole.F/ 947' ~o.1349'.. ' . NOW- Dr. illing @ 1349'. ~80-460' /380-460' Dir drilled 12 1/4" hole f/ 1349' to 1500'. Trip for dyna-drill. Orient DD w/ SDC. DD f/ 1500' to 1571' & steering tool failed. POOF Found Totco ring still in bit sub. Removed Totco ring'. RIH w/ DD. Oriented DD w/ SDC gyF DD 12 1/4" hole f/ 1571' to 1644'. o NOW: Dril-ling:@.1644'. .. Dyna-drilled 12 1/4" hole f/ 1644' to 1830'. POOH. RIH w/ bit #6 on BHA #7 (90' belly). Reamed dyna-drill run f/1621' to 1839'. Ran survey. Directionally drilled 12 1/4" hole f/ 1839' to 1995'. Circ btms up & POOH. .RIH w/ bit #6 on BHA #8 (locked up assembly). 'Tri[ in was smooth. Circ & cond hole for 9 5/8" csg. POOH. Laid down 12 1/4" tools:& 8" DC's. , NOW' Rig up to run 9 5/8" csg.. RU & ran 9 5/8, 47# N-80 buttress csg w/ float shoe @1995' float collar @1946' 380'-460' Ran 5" DP w/ stab-in tool & stabbed in~o FC @ 1946'. Circ & cond for cmt. Cmtd csg w/ 400 sx cl "G" w/ 4% pre-hydrated gel & 2% CaCl2 followed by 250 sx cl "G" w/ 2% CaC12. Displaced 90% of DP. Floats held ok. CIP @ 08:10 hrs 4/16/81. Pulled 2 stands of DP. Lifted BOP & set slips. POOH w/ 5" DP. Raised BOP & cut off 9 5/8" csg. Installed & tested CIW 12" 3m x 12" 3m_..csg spool .w/ 'IR" seals ........ Rein~-tal-led 'BOPs, -Laid down'-'"39-jts of 5" DP. RIH w/ 8 1/2" bit on BHA #9. Tagged cement @1939'. $ 27,681 $ 787,496 $2,360,000 2376'/381' Displaced hole w/ FIW & CO cmt to FC @ 1946'. 16" D. 228' ! Tested 9 5/8" csg to 3000 psi - ok.' Drilled 13 3/8" Window f/I 380'-460' FC & cement to 1990'. Tested csg to 3000 9 5/8" C. 1995' psi - ok. Displaced hole w/ mud & drilled 71 PCF 43 SEC float shoe @1995' and 10' of new hole to · 2005'. Circ & cond mud. Performed leakoff test - shoe held 91 PCF equivalent. POOH. Changed liners in pump. RIH w/ bit #7 on BHA #10 (60' belly). Directionally drilled 8 1/2" hole f/ 2005' to 2318'. Lost pump pressure. POOH - could not find washout. RIH w/ bit #8 on BHA #11 (90' belly) and drilled 8 1/2" hole f/ 2318' to '2339' - lost pump pressure. POOH - found washout in slip area of 23rd jt of "E" DP. RIH & drilled 8 1/2" hole f/ 2339' to 2376'. LEASE Ui' IOI. OIL CAPON OF CALIFOP iIA S ;EET D PAGE ih. ---6 WELL RECORD ADL 18731 $ 'ELL NO, TBS A-9RD FIELD TRADING BAY FIELD DATE 26 4/18/81 DAILY COST- ACC COST.: AFE AMT: 27 4/19/81 DAILY COST- ACC COST. AFE AMT: 28 4/20/81 DAILY COST- ACC COST' AFE AMT: 29 4/z 1/81 DAILY COST: ACC COST--: AFE AMT- 30 4/22/8'i DAILY COST- ACC COST- AFE AMT' ETD ]995'/2940' Continued to directionally drill 8 1/2" hole 16" D. 228' f/2376' to 2709'. POOH. RIH w/ bit #9 on 13 3/8" Window F 380'-460' dyna-drill. Down 4 1/2 hours to fix wireline 9 5/8" C. 1995' unit. Oriented D/D and directionally drilled 71 PCF 43 SEC 8 1/2" hole f/ 2709' to 2772'. $ 26,178 $ 813,674 $2,360,000 3721'/781' 16" D. 228' 13 3/8" Window 9 5/8" C. 1995' 71 PCF 45 SEC $ 25,379 $ 839, 053 Steering tool came unseated - could not reseat. POOH w/ WL. Ran magnetic survey & POOH w/ dyna 380'-460' drill. RIH w/ bit #10 on BHA #13 (90'belly) and directionally drilled 8 1/2" hole f/2772' to 2940'. Continued to drill 8 1/2" hole f/ 2940' to 3027'. Surveyed & POOH. RIH w/ bit #11 on BHA #14. Directionally drilled 8 1/2" hole f/ 3027' to 3721 '. Surveyed & POOH.· $2,360,000 NOW' POOH for bit change. 4381'/660' 16" D. 228' 13 3/8" Window f 3802460' 9 5/8" C. 1995' 73 PCF 43 SEC $ 29,'027 $ 931,920 $2,360,000 · 4895/5i4, 16" D. 228' 13 3/8" Nindow ¢ 9 5/8" C. 1995' 76 PCF 41 SEC $ 29,635 $ .961,555' $2,360,000 5336'/441' .. 16" D. 228' 13 3/8" Window f 380-460' 9 5/8" C. 1995' 76 PCF 41 SEC · $ 28~564 $ 990,119 $2,360,000 POOH. RIH w/ bit #12 on BHA #15 and direc- tionally drilled 8 1/2" hole f/ 3721' to 4111'. POOH. RIH w/ bit #13 on BHA #16 & direc- tionally drilled 8 1/2" hole f/ 4111' to 4381 '. POOH. NOW- POOH for bit Change. Trip for bit change. RIH w/ bit #14 on BHA #17 & directionally drilled 8 1/2" hole f/ 4381' to 4658' 380-460 Trip for bit change RIH w/ bit #15 on BHA #17 & directionally drilled 8 1/2" hole f/ 4658' to 4895' (Raised MW to stop oil cutting the mud @ 4756' MD). NOW- Drilling @ 4895'. Directi°nally drilled 8 1/2" hole f/ 4885' to 4900'. Trip for bit change. RIH w/ bit #16 on BHA #17 and directionally drilled 8 1/2" hole f/ 4900' to 5194'. Trip for bit change. RIH w/ bit #17~on BHA #17 and dir- ectionally drilled 8 1/2" hole f/ 5194' to 5336'. NOW' Drilling @ 5336'. OIL CCI?A ' Y CALIFORNIA I £LL RECORD S ;EET D PAGE ih, -" 7 LEASE ADL 18.7.31 DATE 31 "4/23/8i DAILY COST: ACC COST: AFE'AMT: 32 4/24/81 DAILY COST: .ACC COST: AFE AMT: 33 4/25/81 DAILY COST: ACC COST: AFE AMT: 34 4/26/81 DAILY COST: ACC COST: AFE AMT: 35 4/27/81 DAILY COST: ACC COST: AFE AMT: ETD 5614'/278' 16" D. 228' 13 3/8" Window f 9 5/8" C. 1995' 77 PCF 40 SEC $ 32,-I 19 $1,022,238' $2,360,000 5854'/240' 16" D. 228' 13.3/8" Window f 9 5/8" C. 1995' 77 PCF 40 SEC $ 51,006 $1,009,404 $2,360,000 6102'/248' 16" D. 228' 13 3/8" Window f 9 5/8" C. 1995' 77 PCF 41 SEC $ 39,492 $1,048,896 $2,360,000 6295'/193' 16" D. 228' 13 3/8" Window f 9 5/8" C. 1995' 77 PCF 42 SEC $ 27,984 $1,076,880 $2,360,000 6510'/215' 16" D. 228' 13 3/8" Window f/ 9 5/8" C. 1995' 77 PCF 44 SEC $ 27,905 $1,168,625 $2,360,000 $~ELL NO, TBS A-9RD FIELD TRADING BAY FIELD DETAILS OF OPERATJLO[~S, DESCRIPTIOn. IS .& RESULTS 380-460' Directionally drilled 8 1/2" hole f/ 5336' to 5522'. Trip for Dyna-drill. Oriented Dyna- drill w/ Sperry Sun 80° left of HS. Dyna- drilled 8 1/2" hole f/ 5522' to 5614'. NOW: POOH w/ Dyna-drillo 380'-460" RIH w/ bit #19 on BHA #19. Reamed D/D run f/ 5'523' to 5614' Directionally drilled 8 1/2" hole f/ 56i4' to 5683'. POOH for BHA #20 and directionally drilled 8 1/2" hole f/ 5683' to 5854'. 380'-460' Continued to drill f/ 5854' to 5920'. Trip for bit change. Drilled 8 1/2" hole f/ 5920' to 6069' - had high torque. Trip for bit change. ? 380' -460 ' Drilled 8 1/2" hole f/ 6069' to 6102' Continued to drill 8 1/2" hole f/ 610~' to 6209'. Trip for bit change. Drilled 8 1/2" hole f/ 6209' to 6295'. NOW: Trip for bit change. 380460' .RIH w/ bit #24 on BHA #21. DIrectionally drill.: 8 1/2" hole. f/ 6295' to 6406' Trip for bit change. Drilled 8 1/2" hole ~/ 6406' to 6510'. NOW: Drilling @ 6510'. .. LEASE ADL 18731 OIL Ca'?A N OF CALIFOPC.iIA £LL RECORD S EET D PAGE ih, --- ,q ~ELL NO, TBS A-9RD FIELD TRADING BAY FIELD DATE ETD 36 4/28/81 6904 '/394' 16" D. 228' 13 3/8" Window 9 5/8" C. 1995' 77 PCF 43 SEC o. . DAILY COST' $ 26,817. ACC COST' $1 ;195,442 AFE AMT' $2.,360,000 37 4/29/81 7032'/128-' 16" D. 228' 13 3/8" Window 9 5/'8" C. 1995' 77 PCF 44 SEC DAILY COST: $ 28~ 673 ACC COST: $1,224,115 AFE AMT' 38 4/30/81 $2,36O,O00 7032'/0' 16" D. 228' 13- 3/8" Window 9 5/8" C. 1995' 77 PCF 44 SEC DAILY COST' $ 79, i58 ACC COST: $1,303,273 A~E AMT: 39 5/1/81 DAILY COST' ACC COST: AFE AMT- 4O 5/2/81 DAILY COST' ACC COST' $2,360,00O 7032' TD 6976 ETD (TOC) 9 5/8" C. 1995' 7" C. 7020' FIW $ 253,135 $1,492,568 $2,360,000 7032' TD 6976' ETD (TOC) 9 5/8" C. 1995' 7" C. 7020' FIW $ 37,513 $1,530,000 ,,DETAILS, OF ,,OPERATiO[IS, D~SCRIPTIOI,IS &, R~SULTS, Directionally drilled 8 1/2" hole f/ 6510' to 6904'. f 380-460' ' NOW' Trip for bit change. RIH W/ Bit ~.26 on BHA #21. Directionally Drill ' 8 1/2" Hole F/6904' to 7032'. Short trip. 380-460' Condition Mud & hole for logs. RIH W/ Dll-SP-G NOW- Runnihg logs. Ran.DLL-SP-GR, FDC-CNL-GR & BHC-SONIC-GR-Logs. Loggers TD~12.~. R.I.H. W/ Bit #27 on BHA #21. 380-460' C. O. Fill F/ 7026' to 7032'. CIRC & Cond. Mud & hole for 7" Casing. NOW- P.O.O.H. laying down drill pipe. . ,o Laid down 5" drill pipe. Ran 7" 29# buttress, casing f/ surface to 7020'. Ran P-110 f/ 7020' to 5887' & N-80 f/ surface to 5887'. Landed casing w/ FS @ 7020' & FC @ 6977'. Cmtd 7" thru shoe w/ 1000 sx cl "G" w/ 1.3% D-19 & '2" D-6 mixed in FIW. Bumped plug w/ 2500 psi @ 12'15 hrs 5/1/81. Had full returns during cmt job. Nippled down BOPE. Installed & tested 12" 3M x lO" 5M DCB spool to 5000 psi. Installed & tested BOPE to 2500 psi. RIH w/ 6" bit & 7" scrpr picking up 3 1/2" DP. Tagged FC @ 6976'. Circ clean & POOH. RIH w/ CBL-VDL-GR. Could not work tool below 1200'. POOH w/ CBL. RIH w/ 6" bit & 7" scrpr to FC @ 6976'. Did not see anything on trip in. X-over to FIW. POOH. Ran CBL- VDL-GR f/ 6976' to 3500'. Ran Gyro survey f/ surface to FC @ 6976'. AFE AMT- $2,360,000 LEASE U[1IOI.I OIL Cg'?AtN OF CALIFORHIA . kELL RECORD S} EET D P^aE ih, ADL 18731 ~'ELL HO, TBS A-9RD FIELD TRADING BAY FIELD DATE ETD DETAILS. OF OPERAT.IOItS, DESCRIPTIOI.IS g_RESULTS 41 5/3/81 7032' TD 6508' ETD (Cmt) 9 5/8" C. 1995' 7" C. 7020' FIW DAILY COST- $ 51,753 ACC COST- $1,581,834 AFE AMT' $2,360,000 RIH & circ clean. POOH. Perf'd 4 HPF f/ 6896' to 6900' Set cmt ret on WL @ 6886' RIH w/ 3 1/2" ~P & stabbed into ret @ 6886]. Broke down perfs f/ 6896' to 6900' w/ 4 CFM @ 4400 psi. Sqz'd base of Hemlock to isolate water thru cmt ret @ 6886' w/ 200 sx cl "G" w/ .75% D-31L in FIW. Final rate 2 CFM @ 5900 psi. Left 25 sxs on top of ret. Pulled 2 stds & rev clean. CIP @ 14:35 hrs 5/3/81. POOH. Perf'd 4 HPF f/ 6638' to 6642'. RIH & set ret-a-matic @ 6460' Broke down perfs f/ 6638' to 6642' w/ 11 C~M @ 3700 psi. Sqz'd top of Hemlock for isolation w/ 200 sxs cl ."G" w/ .75% D-31L in FIW. Final rate 4 CFM @ 5600 psi. CIP @ 21:00 hrs 5/3/81. Held press on sqz for 2 hrs. Released tool. NOW- POOH after sqz. 42 5/4/81 DAILY COST: ACC COST- AFE AMT-- 703Z' ~u 6886' ETD (Ret DLI ) 9 5/8" C. 1995' 7" C. 7020' FIW -o -~. $ 32,255 $1,670,824 $2,360,000 - WOC. Repaired gates' in mud tank. RIH w/ 6" bit & 7" scrpr. Tagged cmt @ 6Z[60'. CO hard cmt f/ 6460' to 6750'. Pressure tested sqz //2 perfs f/ 6638' to 6642' & csg to surface to 2800 psi. RI & tagged cmt @ 6781'. CO cmtof/ 6781' to 6886' ETD. Circ clean.& mix KCL WO fluid (3% KCL, -1. 1/2 ppb HEC & 1/2 ppb XC). · · . . NOW- X-Oger to KCL'" 43 515/81 7032' TD 6886' ETD (Ret DI L) 9 5/8" C. 1995' '7" C. 7020' 64 PCF 35 SEC DAILY COST' .$ 20,4:22 ACC COST: $l.,691,246: AFE AMT' $2,360,000 X-over to KCL fluid. POOH. Perf f/ 6826' to 6876' w/ GO Int 4" csg guns loaded w/ 4 HPF. RIH & set Ret-a-matic @ 6772' Broke down for- mation @ 6 CFM w/ 4750 psi. ~umped 1000 gal 12-3 mud acid, did not have any reduction in pressure when acid hit formation, i.e., 15 BPM. @ 5000 psi. Pumped 2000 gal pre-pad, 5000 gal pad. Blender ~roke,down for 5 min.. Resumed pumping (Not6- rate had reduced to 8 BPM @ 5800 psi). Pumped stage l; 2000 gal w/ 2 ppg 100 mesh & Stage 2; 3000 gal w/ 3 ppg 100 mesh. Well sanded,off,w/ 6500, psi when stage. 2 hit perfs. Rev clean. POOH. NOW: RIH w/ bit to CO sand. Ui'IIOH OIL CCi'? N OF CALIFOPC.iIA WELL RECORD SHEET D PAGE ii O, :--10 LEASE ADL 18731 DATE 44 5/6/81 DAILY COS:F: ACC COST' AFE AM f' 45 4/7/81 DAILY COST: ACC COST' AFE AMT' 46 5/8/81 DAILY COST: ACC COST' AFE AMT' 47 5/9/81 DAILY COST' ACC COST' AFE AMT: ETD 7032' TD 6886' ETD (Ret 9 5/8" C. 1995" 7" C. 7020' 64 PCF 35 SEC $ 21,657 $1,712,903 $2,360,000 7032' TD 6812'~ETD (RBP) 9 5/8" C. 1995' 7" C. 7020' 64 PCF 35 SEC $ 33,622 $1,746,525 $2,360,000 7032' TD 6894' ETD (RET) 9 5/8" C. 1995' 7" C. 7020' 64 PCF 35 SEC $ 71,261 $1,761,051 $2,360,000 7032' TD 6886' ETD 9 5/8" C. 1995' 7" C. 7020' 64 PCF 34 SEC $ 324,225 $2,085,276 $2,360,000 I4ELL NO, TBS A-9RD FIELD TRADING BAY FIELD DETAIL. S OF OPERAT. I.OI:tS, DESCRIpTIOH. S & RI~SULTS RIH lo .ret ca 6886' DLL (no sand). Circ clean & POOH. RIH & set baker Ret-a-matic @ 6772'. Broke down formation w/ Howco @ 5800 psi. Pumped' into forma-tion w/ 5400 psi @ 12 CFM, increased rate to 24 CFM & pressure inc to 5800 psi. ' Pumped 1000 gal 12-3 mud acid @ 24 CFM & 5~00 psi. Pressure did no.t decrease when acid hit formation. Shut down.. PressUre bled-to zero in 10 min. (Note- Dowel'l frac pumpS on'ly'good for 4800 psi · -cont. use)-. Released tool, RI & tagged sand @ 6882''DLL. Circ clean to 6886' ' POOH. .Reperf'd .4 HPF w/ GO Int 4" csg guns f./ 6826' toI 6876'. RIH & set Ret-a-matic £a 6772'. ,. ~NOW: Waiting on fluid end for Dowell pump from slope. That is good for 7500 psi. Install high press fluid ends on frac pumps. Broke down perfs f/ 6826' to 6876' w/ Howco & pumped into formation @ 15 CFM w/ 5000 psi. Pumped 4000 gal pre-pad & 8000 gal of pad, pumped 11,000# of 100 mesh in YF4 PSD in three 2000 gal stages w/ 1 ppg in 1st stage, 2 pp§ in'2nd, and 3 ppg in 3rd. Pumped 17,000 gal YF4 PSD in seveD stages w/ I .ppg 20-~0 in 1st stage and 7 ppg in'last, stage. Well sanded ou while disblacing the 7 ppg stage. Total of +_90,000# of 20-40 mesh sand out perfs. PumPed most of frac @ +15 BPM w~ +5500 psi. Pressure up to 7000 ps'i o-n' final sta-ge. Rev clean'. Shut in and' held press of frac for 6 hrs. Re- . leased tool. Tagged sand @ 6855'.. Rev clean sand f/ 6855' to 6870'. POOH. RIH & set Baker retrievable bridge plug @ 6812'. Tested BP to 5800 psi. NOW' Prep to sand out top of bridge plug. Sanded out BP @ 6812' to 6783'. POOH. Perf'd f/ 6730' to 6755' w/ 4" csg gun loaded w/ 4 HPF. (Hole started taking 5 bbls/hr after perforating). RIH & set ret-a-matic @ 6678'. Tested all lines to 6000 psi. Broke down perfs & pumped 30 CFM @ 4000 psi. Mixed & pumped frac #2 as per design @ + 14 BPM w/ 4300 psi. +90,000# 20-40 sand in place @ 12'00 hrs 5/8/81' Held press on frac for 6 hrs. Released tool. Rev out sand to 6806'. POOH. Ran GO Int GR log f/ 6800' to 6500'. GR off scale f/ 6704' to 6720' & f/ 6732' to 6738'. RIH & retrieved BP f/ 6812' & reset BP @ 6725' Hole took +15 bbl/hr until BP was set @ 6725'. Tested BP to 5000 psi. Sanded out BP to 6715' POOH. Perf'd 4-1/2" HPF f/ 6663' to 6693' w/ 4" csg guns. RIH & set ret-a-matic @ 6615'. Tested all lines to 6000 psi. Broke down perfs & pumped @ 24 CFM w/ 4000 psi. Pumped frac #3 as per design @ + 14 BPM w/ 4000 psi. +_95,000# 20-40 sand in pTace ~ 13:15 hrs 5/9/~ Held press on frac for 6 hrs. Released tool. CO sand to 6725' & retrieved BO f/ 6725'. Hol taking fluid @ 32 bbls/hr. Spot 100 bbls WO fluid on btm w/ 25 ppb baracarb. UHIOH OIL CD' ?AI Y OF CALIFOPC,iIA WELL RECORD SI EET D PAGE lb, ...ll LEASE ADL 18731 DATE 48 5/10/81 DAILY COST' ACC COST; AFE AMT- I' 49 ~>/11/81 DAILY COST: ACc COST- AFE AMT- 50 6/4/81 70: 688 95 7" DAILY COST- $ ACC COST- $2 AFE AMT- $2 51 6/5/81 703' 688 95 7 ,! ,.$ · DAILY COST: $ ACC COST' $2, AFE AMT' $2, .. ETD 7032' TD 6600 ETD 9 5/8" C. 1995' 7" C. 7020' 64 PCF 35 SEC $ 106,491 $2,191,767 $2,360,000 7032' TD 6886' ETD (Ret) 9 5/8" C. 1995' 7" C. 7020' $ 101,258 $2,349,760 $2,360,000 ' TU 6' ETD (Ret) 8" C. 1995' · 7020' 26,524 376,284 360,000 ' TD ' ETD (Ret) 8" C. 1995' · 7020' 31,097 [07,381 60,000 % ELL NO, TBS A-9RD FIELD TRADING BAY FIELD ..DF, TAILS OF OP. EP~kT.[OIIS, DESCRIPTIOJ~S & RESULTS. POOH. Ran GR log f/ 6850' to 6500'. GR off scale f/ 6630' to 6642', 6670' to 6684', 670J' to 6720' & 6732' to 6738'. Have some indica- tion of frac f/ 6750' to 6770' also. Reperf'd w/ 4" csg guns w/ 4 1/2" HPF f/ 6755' to 6750' & 6693' to 6663'. RIH & CO to 6886' w/ 6" bit & 7" csg scrpr (tagged fill @ 6861'). Circ clean. POOH. Ran gauge ring & junk basket to 6650'. Set baker mod "D" on WL @ 6600' DLL. RIH & test pkr @ 6600'. POOH laying down DP. NOW: Laying down DP. Layed down 3 1/2" DP.. Ran 2 7/8" 6.4# N-80 buttress tubing w/ 10' of seals & GLV's @ 656 5852' 4913' 3595' & 1995' and Otis BV @ 31 Mule shoe @ 6618'. Displaced annulus w/ pkr fluid. Spaced out &.j.~nded tbg, Installed. removed BOPE, installed & tested CIW single 2 7/8" tree. Released rig to TBS A-24 AFE #- 311001 @ .24'00 hrs' 5/!1/81. - Commenced operations O0'O1 hrs 6/4/81. Killed well; installed BPV, removed tree, installed & tested BOPE. Picked up tbg 40' & circ out sand. Pulled, st.ood back 2 7/8" tbg string. RIH w/ 2 3/8" stinger on 3 1/2" DP. Tagged sand @ 6565'. Circ out sand f/ 6563' to 6625'. Gould not work below 6625'. Trip & reworked mule shoe on 2 3/8" stinger. Circ out sand f/ 6625' to to 6894' (hole started taking fluid @ 6759'). Pumped 50 bbl pi'lls of KCL fluid w/ 20 ppb bara carb to stop lost circ while cleaning out. NOW- Circ.@ 6894'. Pulled out laying down DP. Ran 2 7/8" comp assy. RemoVed BOPE, installed & tested xmas tree. Con- nected flow lines. Released rig to TBS A-17 RD @ 24'00 hr-s 6/5/81. 0216d ORIGIfiAL UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET A PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD SPUD DATE 6/4/81 COMP. DATE 6/5/81 _ FIELD TRADING BAY ~ CONTRACTOR PARKER RIG NO. 56 LOCATION: Conductor #16 1625' S & 5~6' E TYRE UNIT 860 Oilwell of SE Corner of Seption_ 4, TgN, R13W SM DRILL PIPE DESCRIPTION 7,'_ 19.5~ .'E'i ~ 'S~135' PERMIT NO..--~/~'1-~ ~ SERIAL NO. 733-70062-0) TD ·7032' MD TVD 6467' DEVTA'T'IO'N '(BHL)- - 21-97' at-5 86° 28' W COMPANY ENGINEER Watson-Boulware 3 1/2" 13.3# 'E' ELEVATION~:-WAY~R DEPTH 62' RT TO OCEAN FLOOR 174' RT TO GL ll2' RT,.~DRILL DECK22:0~7' RT TO PR~U~ION.DECJ~~ ~.8~' _ APPROVED~ SiZE .... WE-I G-H'T CASING & TUBING RECORD GRADE bE'~H REMARKS 13 3/8" 61# Butt 3-55 1082' Cmtd w/ 1200 sx "G". W/addilti'vieS_i. 13 3/8, Window f/ 380'-460' 9 5/8" 47# Butt N-80 1995' Cmtd w/ 650 sx "G" w/ additivies 7" 29# Butt P-llO to 5887' THREAD N-80 to 7020' 2 7/8" 6.5# But-t N-80 5598' Cmtd w/ 1000 sx "G" _w_/additivies__ _ Dual' 'C'ow~'l'e't i°n Dual Pkr - 4403' 2 3/8" 4/6# Butt DATE INTERVAL E. T]'D. N-80 4427' _ _..S.i.n~le Pkr - 5554' PERFORATING RECORD REA'SON' PRE'SENT CONDITION 5/81 6663-6876' 6886' 6638-6642' 6886' 6896-6900' 6886' - 2784- .... 6270-6310' Hemlock perfs below cmt retainer Sqz'd w/ 200 sx "G" w/ ~'d'd~t'i~es S.qz,'.d w/ 200 sx "G" w/ 'ad'd'itiVes 6480 ' Production 5'8'-'1 ~d Open 6266-6268 ' 6480 ' 5805-5825' 6480-' Sqzd w/138 sx "G" w/ additives_._ Production 54-5 Sd Open 5675-5770' 6480' Production 53-8 S.d Open 5600-5625' .6480' Production 53-0 Sd Open 5590-5592 ' 6480 ' 5425 -5500, -480' Sqzd w/..105 sx "G" w/ additives Production 51'6-Sd- Open 5339-5341' 6480' 5210-5245' 6480' Sqzd w/ 180 sx "G" w/ additives ProdUCtiOn' '50%3' ~d ~Open 5005-5025' 6480' Production 48-7 Sd Open 2/84 4999-5001' 6480' 4611_-4613_' 6_480' 4555-4585" 6480 ' Sqzd w/ 131 sx "G" w/ additives Sqzd w/ 167 sx "G" w/ additives P~odUcti°n 'C'-'~ 'Sd Dpen 4435-4475' 6480' Production C-5 Sd Open 4428-4430' 6480' Sqzd w/ 140 sx "G" w/ additives INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS WELL HEAD ASSEMBLY TYPE: TUBING HANGER: TUBING HEAD TOP: MASTER VALVES: CASING HEAD: CASING SPOOL: CIW 12" 3000 psi x 12. 3000 psi _ _ _ TUBING HEAD: CIW 12" 3000 psi x 7 1/16" 5000 PS~ ...... CIW 2 3/8" Dual DCB CHRISTMAS TREE TOP CONN: 12" - 900 w/ 2" Outlets 12 2/8" SOW Shaffer Model KD, - UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 2 LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS MONOPOD PLATFORM A-9 RD WO (UOCO) AFE #331001 U.O. 50.0% 1D 2/04/84 6886' ETD 9 5/8" 1995' 7" 7020' FIW DALLY COST: $ 23,287 ACC COST: $ 23,287 AFE AMOUNT: $1,120,000 RU & FILL ANNULUS W/ FIW. PUMPED 48 BBLS OF FIW 8 700 PSI. PRESSURE BLED TO ZERO IMMEDIATELY. INSTALL X-O FLANGE ON RISER. RU WL (MEYERS). PULL SSSV, RD (MEYERS) PUMPED 10.6 BBLS FIW TO FILL TBG. PUMPED 50 BBLS (CAC03 20#/BBL) (i#/BBL XC) INTO PERFORATIONS. PRESS INCREASED 700-1000 PSI WHILE PUMPING. ND TREE, NU BOPE. 2 D 2/05/84 6886' ETD 9 5/8" 1995' 7" 7020' FIW DAILY COST: $ 19,017 ACC COST: $ 42,304 AFE AMOUNT: $1,120,000 NU & CHANGE TO 2 7/8" & 3 1/2" RAMS. REPAIR & REPLACE BURNED UP KOOMEY CONTROL LINES. GENERAL RU. TESTING BOPE'S. POORBOY DEGASSER FROZE UP W/ ICE & SAND. THAWED OUT W/ STEAM. 2/06/84 6886' ETD 9 5/8" 1995' 7" 7020' FIW DAILY COST: $ 25,804 ACC COST: $ 68,108 AFE AMOUNT: $1,120,000 TESTBOPE. POOH WITH SINGLE 2 7/8" COMPLETION ASSY. CHANGE PIPE RAMS TO 3 1/2". RIH WITH 6" BIT AND 7".CSG SCRAPER AND TAG PERM PKR ~ 6613' DPM. POOH WITH 3 1/2" D.P. 4 D 2/07/84 DAILY COST: ACC COST: AFE AMOUNT: 6550' ETD (CMT RET) 9 5/8" 1995' 7" 7020' FIW $ 38,617 $ 106,725 $1,120,000 SET EZ DRILL RET AT 6550' DPM. TEMP REP POWER LINE TO HOWCO PUMP. UNABLE TO GET TEST ON BOPE. POOH W/ DP. FIX LEAKS IN DCB SPOOL & TEST BOPE. BLINDS WOULDN'T TEST BUT PIPE RAMS & HYDRIL TESTED OK. RIH W/ DP. STAB INTO CMT RET ~ 6550'. PRESS UP T0'4900 PSI ON SURFACE W/ NO BREAKDOWN OR BLEED OFF. RESTAB W/O SUCCESS. ABANDON HEMLOCK ZONE W/ 35 CU FT OF CMT ON TOP OF CMT RET ("G", .75% CFR-2, .4% HALID 22-A, 1% CACL2) CIP ~ 10:00 RM 2/07/84. POOH W/ DR. NOTHING WRONG W/ STINGER. BLIND RAMS STILL WON'T TEST. RU TO LAY DOWN 2 7/8" TBG. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD 5 D 2/08/84 DAILY COST: ACC COST: AFE AMOUNT: 6550' ETD (CMT RET) 9 5/8" 1995' 7" 7020' FIW $ 20,881 $ 127,606 $1,120,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS FINNISHED LAYING DOWN 2 7/8" TBG. REPAIR BLIND RAMS IN SCHAFFER DBL GATE. FOUND SEVERE WEAR. CLEARANCES BETWEEN SEAT AND RAMP OVER SPECIFICATIONS. REPAIR LEAK IN BRAKE COOLING WATER SYSTEM. INSTALL PERMANENT LEAD AND CIRCUIT BREAKER TO HOWCO UNIT. 6 D 2/09/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' ETD (CMT PLUG) 9 5/8" 1995' 7" 7020' FIW & KCL 68 PCF $ 32,157 $ 159,763 $1,120,000 TEST BORE TO 3000 PSI, OK. CLEAN OUT CMT F/ 6409-6480'. WT UP SYSTEM TO 68 PCF W/ KCL & FIW. RIH W/ WL & PERFORATE F/ 6266-6268' W/ 4 HRF. POOH. RIH W/ GUAGE RING TO 6240'. POOH. 7 D 2/10/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 5290' ETD (CMT RET) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 84,370 $ 244,133 $1,120,000 RIH W/ CMT RET AND SET $ 6228' DIL (6230' CBL) ON WL. RIH W/ DP TAG CMT RET $ 6236 DRM. TEST ALL LINES TO 6000 PSI. BROKE DOWN RERFS W/ 3200 PSI. MIXED 170 SXS, "G", .75% CFR-2, .4% HALID 22A, AND 1% CACL2. DISPLACED 138 SXS BEHIND PERFS W/ FINAL PUMPING PRESSURE OF 4175 PSI. SQZ JOB HELD 2700 PSI W/ RUMPS OFF AFTER 3 MIN. CMT IN PLACE $ 10:42 AM, 2/10/84~ PERFORATED F/ 5590-5592' W/ 2-1/2" HRF. RIH W/ CMT RET ON DR AND SET $ 5554'. TEST ALL LINES. BROKE DOWN RERFS W/ 3100 PSI. MIXED 180 SXS SAME SLURRY AS ABOVE. DISPLACED 105 SXS BEHIND RERFS W/ FINAL PUMPING PRESSURE OF 4250 PSI. SQZ JOB HELD 2250 PSI W/ PUMPS OFF AFTER 3 MIN. CMT IN PLACE ~ 7:25 RM 2/10/84. POOH W/ DP. RU TO PERFORATE NEXT ZONE FOR ISOLATION. LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. A-9 RD WO SHEET D PAGE NO. 4 FIELD TRADING BAY FIELD DATE ETD 8 D 2/11/84 6480' TD (CMT PLUG) 4578' ETD (CMT RET) 9 5/8" C. 1995' 7" C. 7020' F IW & KCL 68 PCF DAILY COST: ACC COST: 86,106 330,239 AFE AMOUNT: $1,120,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS PERFORATED F/ 5339-5341' DIL (5340-5342' CBL) W/ 4-1/2" HOLES 2 HPF. RIH W/ CMT RET ON DP AND SET $ 5290'. TESTED ALL LINES TO 5000 PSI. BROKE DOWN PERFS W/ 3000 PSI. MIXED 200 SXS CLASS "G", .75% CFR-2, .4% HALID 22-A, AND 1% CACL2. DISPLACED 180 SXS CMT BEHIND PERFS W/ FINAL PUMPING PRESS OF 3250 PSI. SQZ HELD 2500 PSI W/ PUMPS OFF AFTER 4 MIN. CIP $ 4:55 AM 2/11/84. PERFORATED F/ 4999-5001' DIL (5000-5002' CBL) W/ 4-1/2" HOLES 2 HRF. RIH W/ CMT RET ON DP AND SET ~ 4951' TEST ALL LINES TO 5000 PSI. BROKE DOWN ~ERFS W/ 3100 PSI. MIXED 150 SXS SAME SLURRY AS ABOVE. DISPLACED 131 SXS CMT BEHIND RERFS W/ FINAL PUMPING PRESSURE OF 3550 PSI. SQZ HELD 2300 PSI W/ RUMPS OFF AFTER 4 MIN. CIR $ 11:22 AM 2/11/84. ~PERFORATED F/ 4615-4617' DIL (4617-4619' CBL) W/ 4-1/2" HOLES 2 HRF. RIH W/ CMT RET ON DR AND SET $ 4578' TEST ALL LINES TO 5000 PSI. BROKE DOWN ~ERFS W/ 2900 PSI. MIXED 160 SXS SAME SLURRY AS ABOVE. DISPLACED 142 SXS CMT BEHIND RERFS W/ FINAL PUMPING PRESSURE OF 3300 PSI. SQZ HELD 2200 PSI W/ PUMPS OFF AFTER 3 MIN. CIP $ 6:04 PM 2/11/84. PERFORATED F/ 4428-4430' DIL (4430-4432' CBL). RIH W/ CMT RET ON DP. 9 D 2/12/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 4575' ETD (CMT) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 32,901 $ 363,140 $1,120,000 SET CMT RET $ 4395' ON DP. TESTED ALL LINES TO 5000 PSI. BROKE DOWN PERFS W/ 2900 PSI. MIXED 160 SXS CLASS "G", .75% CFR-2, .4% HALAD 22-A 1% CACL2. DISPLACED 140 SXS CMT BEHIND PERFS W/ FINAL PUMPING PRESSURE OF 3100 PSI. SQZ HELD 1600 PSI W/ PUMPS ,OFF AFTER 3 MIN. CIP ~ 1:20 AM 2/12/84. POOH W/ DP. CHANGE OUT DCB SPOOL. INSTALL CIW 13 5/8" (3000) X 7 1/16" (5000) DCB SPOOL & "XO" TO RISER. RIH W/ 6" MILL AND CO TO 4575'. 10 D 2/13/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 24,172 $ 387,312 $1,120,000 POOH W/ 6" MILL. RIH W/ 6" BIT. DRILL ON CMT RET $ 4578'. DRILL UP SAME. CO SOFT CMT F/ 4579-4594'. CO FIRM CMT F/ 4594- 4655'. RIH TO 4951'. DRILL ON CMT RET. TRIP FOR NEW BIT. DRILL UP RET $ 4951'. CO SOFT CMT F/ 4952-5016'. RIH AND TAG CMT $ 5266'. CO CMT TO 5290'. DRILL ON CMT RET $ 5290'. CHASE RET TO 5306'. DRILL UP SAME. CO HARD CMT F/ 5306-5358'. CO STRINGERS F/ 5358-5532'. CO FIRM CMT F/ 5532-5554'. DRILL ON CMT RET ~ 5554. TRIP FOR NEW BIT. LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. A-9 RD WO SHEET D 5 PAGE NO. FIELD TRADING BAY FIELD DATE ETD 11 D 2/14/84 6480' TD (CMT PLUG) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF DAILY COST: ACC COST: AFE AMOUNT: $ 21,133 $ 408,445 $1,120,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RIH W/ NEW BIT. DRILL ON CMT RET $ 5554'. NO CMT F/ 5555-5559'. HARD CMT F/ 5559- 5602'. STRINGERS TO 5643'. RIH TO 6236'. DRILL ON CMT RET. CO TO 6480'. POOH. PU 6" BIT & 7" SCRAPER. RIH. CIRC & POOH. RU DRESSER ATLAS TO RUN GR, CBL, CLL. 12 D 2/15/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 54,139 $ 462,584 $1,120,000 COMPLETE CBL, GR, CLL. RUN DRY TEST W/ 1000 PSI BHP ON THE "D" & "E" ZONES. NO ENTRY. RUN DRY TEST W/ 1000 PSI BHR ON THE "C" ZONE. NO ENTRY. RU TO RESQUEEZE BELOW THE C-6 SAND. SET CMT RET $ 4653' DIL ON WL. PERFORATE F/ 4611-4613' DIL. SET CMT RET $ 4574' DRM. TEST LINES TO 5000 PSI STING INTO CMT RET AND PUMP INTO FORMATION ~ 3200 PSI ~ 5 CFM. PUMPED CMT. WHEN CMT ENTERED PERFORATIONS THE PRESSURE INCREASED TO 6500 PSI IMMEDIATELY AND BURST CMT LINE ON THE SURFACE. CHANGE OVER CMT LINES, (+ 5 MINS) AND REVERSED OUT CMT. POOH W/ D.P. LAY DOWN STINGER. NO VISIBLE DAMAGE. 13 D 2/16/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 27,911 $ 490,495 $1,120,000 RIH W/ 6" MILL. TAGGED AND MILLED ON CMT RET AND CMT $ 4578'. PUSH RET TO 4661' DPM. POOH. PU BIT & SCRAPER & RIH TO 4661' DPM. CIRC BTMS UP. POOH. RATTLE DP NO SCALE.. RIH TO 4653' DIL W/ JUNK BASKET ON WL. POOH. PERFORATE 4611-4613' DIL. RIH W/ CMT RET ON DP AND SET 8 4569' DPM. TEST SURFACE LINES TO 5000 PSI. STING INTO RET AND PRESS UP TO 6000 PSI W/ NO BREAK DOWN. FOUND FINES IN MUD PLUGGING RETAINER. DUMPED PITS & DISPLACED HOLE W/ FIW. RU CMT LINES. BROKE DOWN FORMATION $ 3000 PSI & 23 CFM. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 6 LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 14 D 2/17/84 4480' TD (CMT PLUG) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 RCF DAILY COST: $ 35,660 ACC COST: $ 526,155 AFE AMOUNT: $1,120,000 FINISHED CLEANING MUD SYSTEM TANKS. PUMPED 167 SXS CMT BELOW CMT RET ~ 4569' DPM (FIW, · 75% CFR-2, .4% HALAD 22A, 1% CACL2) W/ FINAL PUMPING RATE OF 5 CFM ~ 2500 PSI. SQZ JOB HELD 2000 PSI W/ PUMPS OFF AFTER 5 MIN. CIP ~ 3:00 AM, 2/17/84. POOH W/ DP. RIH W/ 6" BIT. CO CMT F/ 4566-4569'. DRL UP CMT RET ~ 4569'. CO CMT F/ 4572-4640' STRINGERS TO 4660'. DRL ON CMT RET ~ 466~-4662'. POOH W/ DP. RU 6" JUNK MILL & RIH. 15 D 2/18/84 6477' TO (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF DAILY COST: $ 26,158 ACC COST: $ 552,313 AFE AMOUNT: $1,120,000 RIH & MILL ON CMT RET ~ 4662'. RIH TO 6477' ETD. SWEEP HOLE W/ VISCOUS PILL. POOH. PU 6" BIT & 7" SCRAPER. RIH TO 6477' CIRC HOLE CLEAN. POOH. PU TEST ASSY ~ RIH. LOAD DP W/ 1050 PSI GAS. SET RTTS~ 4375'. BLEED OFF GAS. RUN DRY TEST ON "C" ZONE SQZ PERFS. 19 BBLS/ DAY OF FLUID ENTRY. TEST OK. FILL HOLE & REVERSE OUT. RIG DOWN SURFACE LINES. 16 D 2/19/84 4477' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' PERF PILL (77 PCF f/ 6477-3000') (68 PCF f/ 3000'-SURFACE) DAILY COST: $ 42,953 ACC COST: $ 595,266 AFE AMOUNT: $1,120,000 POOH. LAY DOWN RTTS. RIH OPEN ENDED TO 6477'. MIX 77 PCF SAFE LINK COMPLETION SYSTEM AND BALANCE F/ 6477-3000'. POOH. TEST BOPE. RU DRESSER ATLAS. RIH W/ 20', 5" CSG GUN. GUN STOPPED ~ 4611! (BTM OF GUN). POOH. RIH W/ 10', 5" CSG GUN. GUN STOPPED 4611'. POOH. RIH W/ 6" TAPERED MILL AND REAM THRU TIGHT SPOT ~ 4613-4615' DPM. TORQUE VARIED F/ 200-400 AMPS. MILLED TIGHT SPOT UNTIL TORQUE FELL OFF TO NORMAL. POOH. RU DRESSER ATLAS. RIH W/ 20', 5" CSG GUN. 17 D 2/20/84 6477' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 68 PCF DAILY COST: $ 35,820 ACC COST: $ 631,086 AFE AMOUNT: $1,120,000 RIH W/ 2Q', 5" CSG GUN. GUN STOPPED AGAIN ® 4611' WLM. POOH. PU 4" GUN & RIH TO 6314' WLM W/ NO PROBLEMS. POOH. RU DIALOG MIN I.D. CALIPER TOOL. LOG F/ 5700' - SURFACE. LOG SHOWS I.D. OF 7" CSG TO BE AS SMALL AS 5 7/8" IN PLACES. RU 10', 4" CSG GUN & RIH. PERFORATE F/ 6310-6300' DIL. TAGGED FILL $ 6358' WLM. POOH W/ WL~ PU 6" BIT & 7" SCRAPER & RIH. TAG FILL ~ 6367' DPM. CIRC THRU FILL TO 6477' TD. FILL CONSISTED OF SALT PARTICLES F/ PERF PILL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 18 D 2/21/84 6477' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' (74 PCF SAT'D BRINE) (77 PCF PERFORATING PILL) DAILY COST: $ 48,640 ACC COST: $ 679,726 AFE AMOUNT: $1,120,000 19 D 2/22/84 6477' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' (74 PCF SAT' BRINE) (77 PCF PERFORATING PILL) DAILY COST: $ 30,530 ACC COST: $ 710,256 AFE AMOUNT: $1,120,000 20 D 2/23/84 6477' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7"'C. 7020' 90 PCF (SURFACE-4350' 77 PCF (4350-6477') DAILY COST: $ 91,281 ACC COST: $ 801,537 AFE AMOUNT: $1,120,000 CIRC WELL CLEAN. DUMP & CLEAN MUD SYSTEM. MIX 400 BBLS OF SATURATED NACL BRINE. MIX 150 BBLS SAFE LINK PERFORATING PILL. SPOT 'PERFORATING PILL F/ 6477 - +2700'. POOH W/ DP. RIH W/ WL AND PERFORAll~F/ DIL W/ 4" CSG GUNS, 4 HPF, 120° PHASING. NO FILL ON BTM OF HOLE. PERFORATED THE FOLLOWING INTERVALS: 6270-6300', 5805-5825', 5675-5770', 5600-5625', 5485-5500' W/ 4" CSG GUNS, 8 HPF, 120° PHASING. PERFORATED F/ 5465-5485' DIL. TOOK 10 BBL GAIN WHILE PULLING WL OUT OF HOLE. SHUT WELL IN ~ 1:50 AM. CSG PRESS 320 PSI. STRIP IN HOLE W/ CMT RET ON WL. SET CMT RET ~ 4350' CBL. BLED PRESSURE. OFF ~ SURFACE. RIH W/ STINGER ON DP. BUILD SAFE LINK COMPLETION SYSTEM TO 90 PCF. STAB INTO RET AND CHECK FOR FLOW. ZERO PSI ON DR ~ SURFACE. POOH W/ DR. RIH W/ 6" BIT. BUILD SURFACE VOLUME TO 90 PCF. 21D 2/24/84 6466' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 88 PCF DAILY COST: $ 33,075 ACC COST: $ 834,612 AFE AMOUNT: $1,120,000 RIH W/ 6" BIT. DRILL UP CMT RET ~ 4350' CBL (4363' DPM). CIRCULATE AND CHASE CMT RET TO 6466' DPt. BUILD SALT COMPLETION SYSTEM TO 88 PCF. PERFORATED THE FOLLOWING INTERVALS THROUGH OPEN ENDED DP SET ABOVE EACH SAND. PERFORATE W/ 2 1/8" CARRIERS, 4 HPF, 0° PHASING; 5425-5429' (51-6 SD) DIL, 5210-5214' (50-3 SD) DIL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 22 D 2/25/84 6466' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 87 PCF DAILY COST: $ 33,412 ACC COST: $ 868,024 AFE AMOUNT: $1,120,000 CONTINUE PERFORATING THE FOLLOWING INTERVALS THROUGH OPEN ENDED DP W/ 2 1/8" CARRIERS, 4 HPF, 0° PHASING; 5005-5009' (48-7 SD) DIL, 4555-4559' (C-6 SD) OIL, 4435-4439' (C-5 SD) DIL. OBSERVED NO FLOW INTO WELLBORE. POOH W/ DP. PERFORATED THE FOLLOWING INTERVALS W/ 4" CSG GUNS, 4 HRF, 120° PHASING TO A FINAL SHOT DENSITY OF 8 HRF; 5485-5425' (51-6 SD) DIL, 5230-5245' (50-3 SD) DIL. TOOK ll BBL GAIN IN FIVE HOURS. RIH W/ DP. 23 D 2/26/84 6466' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 87 PCF DAILY COST: $ 44,886 ACC COST: $ 912,910 AFE AMOUNT: $1,120,000 RIH TO 6310'. CIRC FLUID. HAD SOME 83 PCF COMP FLUID TO SURFACE. BUILD WT TO 88 PCF. POOH W/ DP. PERFORATE THE FOLLOWING INTERVALS W/ 4" CSG GUNS, 4 HPF, 120° PHASING TO A FINAL SHOT DENSITY OF 8 HPF; 5210-5230' (50-3 SD) DIL, 5005-5025' (48-7 SD) DIL, 4555-4585' (C-6 SD) DIL, 4435-4475' (C-5 SD) DIL. RIH W/ 6" BIT & 7" CSG SCRAPER ON DP. TAG FILL ~ 6226' DPM. CO SALT & PERFORATING DEBRIS TO 6466'. 24 D 2/27/84 6466' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 87 PCF DAILY COST: $ 25,177 ACC COST: $ 938,087 AFE AMOUNT: $1,120,000 CO FILL (SALT AND PERFORATING DEBRIS). POOH W/ DP. RIH W/ 5.782" GAUGE RING AND JUNK BASKET ON WL TO 6400'. POOH W/ WL. RIH W/ BAKER MODEL "D" PERM RKR AND SET 8 5544' DIL ON WL. POOH W/ WL. RIH W/ BAKER SEAL ASSY ON DR & TAG RKR 8 5557' DPM. TEST RKR TO 400 PSI (OK). POOH LAYING DOWN DP. RU TO RUN DUAL 2 3/8" COMPLETION ASSY. 25 D 2/28/84 6466' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 87 PCF DAILY COST: ACC COST: $ 416,026 $1,354,113 AFE AMOUNT: $1,120,000 RUN DUAL 2 3/8" COMP ASSY. SPACE OUT & LAND TBG. PULL DUMMY SSSV IN SS. RUN "N" TEST PLUG IN SS TO "XN" BELOW HYD PKR. ATTEMPT TO SET HYD PKR W/O SUCCESS. CHANGE OUT "N" TEST PLUG & RIH & SET IN "XN". SET DUAL HYD PKR. POOH W/ TEST PLUG. SET SSSV'S IN LS & SS. SET BPV'S IN LS & SS. NIPPLE DOWN BOPE. LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. A-9 RD WO SHEET D PAGE NO. FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 26 D 2/29/84 6466' TD DAILY COST: ACC COST: ND BORE. NU DUAL 2 3/8" X-MAS TREE & TSTD TO (CMT PLUG W/ SUNK ON TOP) 5000 PSI. PULL BPV'S. PULL SSSV IN SS. OPEN 9 5/8" C. 1995' 7" C. 7020' $ 26,294 $1,380,407 "XA" SLEEVE ABOVE DUAL HYD PKR. SET "N" PLUG IN TAIL OF SS. DISPLACE ANNULUS W/ CLEAN FIW. CLEAN MUD PITS. POOH W/ "N" PLUG. CLOSE "XA" SLEEVE. INSTALL SSSV IN SS. RELEASE CREWS F/ AFE # 331001 ~ 24:00 HRS, 2/29/84. AFE AMOUNT: $1,120,000 LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. A-9 RD SHEET D PAGE NO. FIELD TRADING BAY 1.0 DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS DESCRIPTION Monopod Conductor #16 20" DRIVE PIPE LENGTH BTM TOP 179.0 179.0' 0.0' 3TS 25 13 3/8" CASING DETAIL DESCRIPTION Baker Flexi-flow Shoe 13 3/8" 61#, 0-55 Armoo Seal-Look Baker Flexi-flow Collar 13 3/8" 61#, 0-55 Armco Seal-Lock Shaffer Fin Joint Landed below Rotary Table LENGTH BTM 2.10' 1082.00' 38.82' 1079.10' 1.90' 1041.08' 990.76' 1039.18' 8.42' 48.42' 40.00' 40.00' TOP 1079.10' 1041.08' 1039.18' 48.42' 40.00' 45 26 145 Float Shoe 9 5/8" 47# N-80 Buttress Float Collar 9 5/8" 47# N-80 Buttress Landed below zero Howoo Float Shoe 7" 29# P-Il0 Howco Float Collar 7" 29# P-110 7" 29# N-80 Pup Ot 7" 29# N-80 Cut off 7" 29# N-80 Landed Below Zero 9 5/8" CASING DETAIL 7" CASING DETAIL 1.60' 1995.00' 1993.40' 45.70' 1993.40' 1947.70' 1.56' 1947.70' 1946.14' 1908.14' 1946.14' 38.00' 38.00' 38.00' 1.88' 7020.20' 7018.32' 39.76' 7018.32' 6978.56' 1.70' 6978.56' 6976.86' 1089.63' 6976~86' 5887.23' 20.28' 5887.23' 5866.95t 5798.34' 5866.95' 68.61' 31.41' 68.61' 37.20' 37.20' 37.20' LEASE TRADING BAY STATE SHEET D PAGE NO. UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. A-9 RD FIELD TRADING BAY 11 DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS SHORT STRING TUBING DETAIL TOP BTM LENGTH STS DESCRIPTION 4427.89' 4428.50 4427.44' 4427.89' 4426.74' 4427.44' "4411.59' 4425.74' 4411.29' 4411.59' 4408.73' 4411.29' 4405.33' 4408.73' 4403.08' 4405.33' 4402.55' 4403.08' 4375.05' 4402.55' 4372.38' 4375.05' 4371.68' 4372.38' 4342.23' 4371.68' 4336.43' 4342.23' 4335.73' 4336.43' 4303.42' 4335.73' 4297.32' 4303.42' 4049.37' 4297.32' 4043.32' 4049.37' 3703.18' 4043.32' 3693.38' 3703.18' 3535.04' 3693.38' 3529.24' 3535.04' .61' .45' .70' 15.05' .40' 2.56' 3.40' 2.25' .43' 27.60' 2.67' .70' 29.45' 5.80' .70' 32.31' 5.10' 247.95' 5.05' 340.14' 9.80' 158.34' 5.80' 1 1 1 8 11 5 Baker Wireline Entry Guide Otis 2 3/8" X-N Nipple 2 3/8" Butt Coupling 2 3/8" Butt 4.5# Pup Ot 2 3/8" Butt Pin x 2 3/8 l0 Rnd Box X-Over Tail Below Packer Packer Body to Packoff Packer Body from Packoff Baker Left Hand Safety Sub Tack Welded to Pkr Body 2 3/8" 4.5# Butt Otis 2 3/8" X-N Nipple 2 3/8" Butt Coupling 2 3/8" 4.5# Butt 2 3/8" GLM 2 3/8"'Butt Coupling 2 3/8" 4.5# Butt 2 3/8" Butt Pup Ot 2 3/8" 4.5# Butt 2 3/8" Butt Pup Ot 2 3/8" 4.6# Butt 2 3/8" Butt Pup St 2 3/8" 4.6# Butt 2 3/8" GLM LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. A-9 RD SHEET D PAGE NO. 12 FIELD TRADING BAY DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS SHORT STRING TUBING DETAIL TOP BTM LENGTH JTS DESCRIPTION 3528.54' 3529.24 .70' 3064.14' 3528.54' 464.40' 3058.09' 3064.14' 6.05' 2313.90' 3058.09' 744.19' 2307.77' 2313.90' 6.13' 2180.96' 2307.77' 126.81' 2175.16' 2180.96' 5.80' 2174.46' 2175.16' .70' 337.09' 2174.46' 1837.37' 335.39' 337.09' 1.70' 334.69' 335.39' .70' 53.05' 334.69' 281.64' 38.81' 53.05' 14.24' 37.92' 38.81' .89' 37.13' 37.92' .79 36.13' 37.13' 1.00' 0 36.13' 36.13' 15 24 2 3/8" Butt Coupling 2 3/8" 4.6¢~ Butt 2 3/8" Butt Pup St 2 3/8" 4.6¢~ Butt 2 3/8" Butt Pup St 2 3/8" 4.6~ Butt 2 3/8" Butt GLM 2 3/8" Butt Coupling 2 3/8" 4.6~ Butt Otis 2 3/8" XEL Ball Valve 2 3/8" Butt Coupling 2 3/8" 4.6~ Butt 2 3/8" Butt Pup Ot 2 3/8" Butt x 2 3/8" 8 Rnd X-Over Tubing Hanger Standoff DCB to Rig Floor LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. A-9 RD SHEET D RAGE NO. FIELD TRADING BAY 13 DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS LONG STRING TUBING DETAIL TOP BTM LENGTH JTS . ,, DESCRIPTION 5597.56' 5598.26' 5582.44' 5597.56' 5581.99' 5582.44' '5581.29' 5581.99' 5566.14' 5581.29' 5565.38' 5566.14' 5554.78' 5565.38' 5553.73' 5554.78' 5552.97' 5553.73' 5542.92' 5552.97' 5536.'79' 5542.92' 5530.66' 5536.79' 5528.19' 5530.66' 5527.49' 5528.19' 5517.41' 5527.49' 5517.ii' 5517.4i' 5516.4i' 5517.ii' 5515.2i' 5516.41' 5430.2i' 5515.2i' 5390.33' 5430.21' 5388.53' 5390.33' 5263.80' 5388.53' 5261.72' 5263.80' 5260.52' 5261.72' .70' 15.12' .45' .70' 15.15' .76' 10.60' 1.05' .76' io.o5' 6.13' 6.13' 2.47' .70' 10.08' .30' .70 1.20' 85.00' 39.88' 1.80' 124.73' 2.08' 1.20' Mule Shoe 2 3/8" Butt Pup Ot Otis'2 3/8" "X" Nipple 2 3/8 Butt Coupling 2 3/8" Butt Pup Ot 2 3/8" But X 2 7/8" Butt X-Over Seal Assembly for Baker Model "D" Packer Locator Sub 2 7/8" Butt4 X 2 3/8" Butt X-Over 2 3/8" Butt Pup St 2 3/8" Butt Pup Ot 2 3/8" Butt Pup Ot Otis 2 3/8" "X-A" Nipple 2 3/8" Butt Coupling 2 3/8" Butt Pup Ot 2 3/8" Butt X 2 7/8" Butt X-Over 2 7/8" Butt Coupling 2 7/8" Butt X 2 7/8" Hydril X-Over 2 7/8" Hydril Blast Joints 2 7/8" 6.5# Hydril (Blank above Carbide Rings) ' 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" 6.5# Butt 2 7/8" Butt Pup Ot 2 7/8" Butt X 2 7/8" Hydril X-Over LEASE TRADING BAY STATE UNION OIL COHRANY OF CALIFORNIA WELL RECORD · WELL NO. A-9 RD SHEET D PAGE NO. FIELD TRADING BAY 14 DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS LONG STRING TUBING DETAIL TOP BTH , ~ LENGTH STS DESCRIPTION 5215.52' 5260.52' 5197.42' 5215.52' '5195.62' 5197.42' 5040.46' 5195.62' 5039.26' 5040.46' 5009.26' 5039.26' 5007.38' 5009.26' 5005.58' 5007.38' 4612.82' 5005.58' 4606.72' 4612.82' 4600.69' 4606.72' 4599.49' 4600.49' 4559.49' 4599.49' 4536.19' 4559.49' 4534.52' 4536.19' 4503.32' 4534.52' 4493.31' 4503.32' 4491.06' 4493.31' 4489.86' 4491.06' 4439.86' 4489.86' 4426.33' 4439.86' 45.00' 18.10' 1.80' 155.16' 1.20' 30.00' 1.88' 1.80' 392.76' 6.10' 6.03' 1.20' 40.00' 23.30' 1.67' 31.20' 10.01' 2.25' 1.20' 50.00' 13.53' 13 2 7/8" Hydril Blast Sts 2 7/8" 6.5# Hydril (Blank above Carbide Rings) 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" 6.5# Butt 2 7/8" Butt X 2 7/8" Hydrill X-Over 2 7/8" Hydril Blast Jnt 2 7/8" 6.5# Hydril (Blank above Carbide Rings) 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" 6.5# Butt 2 7/8" 6.5# Butt Pup Jt 2 7/8" 6.5# Butt Pup St 2 7/8" Butt X 2 7/8" Hydril X-Over 2 7/8" Hydril Blast Ot 2 7/8" 6.5# Hydril (8lank above Carbide Rings) 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" 6.5# Butt 2 7/8" 6.5# Butt Pup St 2 7/8" 6.5# Butt Pup Ot 2 7/8" Butt X 2 7/8" Hydril X-Over 2 7/8" Hydril Blast Ont 2 7/8" 6.5# Hydril (Blank above Carbide Rings) LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. WELL NO. A-9 RD FIELD TRADING BAY 15 DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS LONG STRING TUBING DETAIL TOP BTM 4424.56' 4426.33' 4424.16' 4424.56' 4423.46' 4424.16' ~4420.88' 4423.46' 4420.18' 4420.88' 4410.45' 4420.18' 4410.05' 4410.45' 4408.73' 4410.05' 4405.33' 4408.73' 4403.23' 4405.33' 4400.91' 4403.23' 4400.31' 4400.91' 4368.29' 4400.31' 4365.74' 4368.29' 4365.04' 4365.74' 4337.25' 4365.04' 4331.45' 4337.25' 4330.75' 4331.45' 3701.02' 4330.75' 3695.22' 3701.02' 3694.52' 3695.22' 3569.59' 3694.52' 3565.96' 3569.59' 3536.16' 3565.96' 3530.01' 3536.16' LENGTH 1.77' .40' .70' 2.58' .70' 9.73 .40' 1.32' 3.40' 2.10' 2.32' .60' 32.03' 2.55' .70' 27.79' 5.80' .70' 629.73' 5.80' .70' 124.93' 29.80' 6.15' STS DESCRIPTION 2O 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" Butt Coupling 2 3/8" Otis "XA" Nipple 2 3/8" Butt Coupling 2 3/8" 4.6# Butt Pup St 2 3/8" Butt X 2 3/8" 10 Rnd X-Over Long String Tail Below Packer Body Packer Body Below Packoff Packer Body Above Packoff Sub above Packer 2 3/8" 10 Rnd X 2 3/8" Butt X-Over 2 3/8" 4.6# Butt 2 3/8" Otis "XA" Nipple 2 3/8" Butt Coupling 2 3/8" 4.6" Butt GLM 2 3/8" Butt Coupling 2 3/8" 4.6# Butt GLM 2 3/8" Butt Coupling 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup St 2 3/8" 4.6# Butt ~ 2 3/8" 4.6# Butt Pup St ~ LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. A-9 RD SHEET D PAGE NO. FIELD TRADING BAY 16 DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS LONG STRING TUBING DETAIL TOP BTM , ~ 2212.62' 3530.01' 2206.82' 2212.62' 2206.12' 2206.82' 2141.81' 2206.12' 2135.69' 2141.81' 1610.15' 2135.69' 1604.05' 1610.15' 1296.31' 1604.05' 1290.19' 1296.31' 710.66' 1290.19' 704.59' 710.66' 433.43' 704.59' 427.39' 433.43' 335.92' 427.39' 334.2~' 335.92' 333.52' 334.22 210.57' 333.52' 204.56' 210.57' 84.86' 204.56' 78.73' 84.86' 46.56' 78.73' 42.15' 46.56' 38.94' 42.15' 37.92' 38.94' 37.13' 37.92' 36.13' 37.13' 0 36.13' LENGTH 1317.39' 5.80' .70' 64.31' 6.12" 525.44' 6.110' 307.74' 6.12' 579.53' 6.07' 271.16' 6.04' 91.47' 1.70' .70' 122.95' 6.01' 119.70' 6.13' 32.17' 4.41' 3.12' 1.02' .79' 1.O0' 36.13' ,]TS 42 2 17 10 19 9 3 4 4 1 DESCRIPTION 2 3/8" 4.6# Butt GLM 2 3/8" Butt Coupling 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup Ot 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup at 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup at 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup at 2 3/8- 4.6# Butt Otis XEL 8V Nipplie #18709-108754 2 3/8" Butt Coupling 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup Ot 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup at · 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt PUp St 2 3/8" 4.6# Butt Pup at 2 3/8" 4.6# Butt Pup St Hanger Stand Off DCB to Rig Floor ''" T,B.S. A'9RDWORKOVER ~, · CASING & ABANDONMENT DETAIL I. R.T. ~ 0' I!' ]--] ] ]II. CIW DCB Tubing Hanger 12", 3000# x 7 1/16" 5000# ~ 37'13 ~ ~ A III. 13 3/8", 61~, J-55 Butt-csg ~ 1,082'(cmtd w/12C0sx) -- -- IV.' 9 5/8", 47#, N-80 Butt csg. ~ 1,995' (cmt'd w/~50 sxs) i i V Top of cement plug $ 6,480' · ' VI. Cemen~ Re~ainer ~ 6,550' w/60 sxs cm~ above ret ~ B VII 7" 29# P-110 & N-80 Bu~ csg ~ 7,020' (cm~O w/!O00 sxs "'- ' ~ I TUBING DETAIL ~ ~ ~' c 2 7/8',6.5~ & 2 3/8' 4.6~,N-80,BUTT. TUBING ; -- '- LONG STRING 4 .___~_ ~ D .j 1. O~is XEL Ball Valve Nipple ~ 334.22' IV- L_ 2-4 2 3/8" Side Pocket G L M ~ 2206 82 , 3695.22' ~ 4331.45' ' O x__~' ~ E 5. 2 3/8" Otis "XA" Sleeve @ 4365.74' 6~i Z ~ F 6' Baker ~odel "A-5" Dual Packer 4403.23' , 7.. 2 3/8" Otis "XA" Sleeve ~ 4420.88' 7 x-~! , 8. 2 3/8"x2 7/8" Buttress Cross-over ~ 4424.16' --- x'-~' G 9-13. Carbide Blast Joints, 9) 4439.86-4489.86' 10) 8I ~ -- . 'C ZONE 4559.49-4599.49', ll) 5009.26-5039.26' 12) ' 5215.52-5260.52, 13) 5430.21-5515.21' · 91 [ C-5 Sd.!i 14 2 7/8"x2 3/8, Buttress Cross-over ~ 5517.11' 15. 2 3/8" Otis "XA" Sleeve ~ 5528.19' ,ol 17. Locator Sub ~ 5553.73' , i 18&l~. Baker Model "D" Packer ~ 5553.73' (5544' DIL) w/lO.6' . Seal Assy ~ 5554.78' Ii Sd. ii 20. 2 7/8" x 2 3/8" Buttress X-over ~ 5565.38 21. 2.3/8" Otis "X" Nipple'~ 5581.~9' 22, Mule Shoe ~ 5597.56' i I50-3 ~i SHORT STRING 12 Sd. ~i A; 2 3/8" 0t±s XEL Ba[[ VaZue ~ ~5.3~' i B-D. 2 3/8" Side Pocket G L.N ,~ 2175 16' C) '~! i51-6 ~352~.24', D) 4336.43' . Sd. ii E. 2 3/8" Otis "XA" Sleeve ~ 4372.38' ' " F. Baker Model A-5 Dual Packer ~ 4403.08" 14 i i G. 2 3/8" Otis "XN" Nippl'e @ 4427.44' 15 ~ ' NOTES' MINIMUM I.D. IN "XA" SLEEVES(1.875") HYDRIL ~ ' :, , to BUTTRESS CROSSOVER. BETWEEN BLAST JOINTS ' PERFORATION RECORD 18 E~I9 ~ ~ Date Interval Condition 20 5-81 6663-6876 Hemlock perfs below cmt retainer D zoNE 6638-6642 Sqzed w/200 sxs "G" w/additives 21 6896-6900 .Sqzed w/200 sxs "C" w/additives 22 5~-0 Sd.~i 2-84 ~:6270-6310 58-1 sand open for production ~ 626b-624~' Sqzed for isolation I 53-8 Sd. ii .5805-5825 54-5 sand open for production 54-5 SdJl 5675-5770 .53-8 sand open for production i E ZONE 5600-5625 53-0 s. and open for production 58-1 Sd. ii ,, 5590-5592 Sqzed for isolation '~ -- .5425-5500 51-6 sand open for production V ~, 5339-5341 Sqzed for isolation VI ~ ' - 5210-5245 50-3 sand open for production :-'i 49~-5001 Sqzed for isolation HEMLOGK ii ' 4615-4617 SqzeO for isolation PERF$. ~i ~4555-4585 C-6 sand opeq for production .~i 4435-4475 C-5 sand open for production VII- - 4428-4430 Sqze~ f.o.r isolation Il Il REV. ' DATE DRAWN B.A,W., CKDJ~ ,- T B.S A-9RD WORKOVER · · SCALE NONE · WELL SCHEMATIC ~ ~'~'~ COMPLETED ' 2/84 UNION OIL COMPANY OF CALIFORNIA , FORM V 247 A 5/56 750 -, "* 0216d UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE TRADING BAY STATE WELL NO. A-9 RD FIELD TRADING BAY LOCATION: Conducto~ #16 16~5' S & 566' E SPUD DATE CONTRACTOR TYPE UNIT SHEET A ~~ PAGE NO..;_ .... 614181 COMP. DATE 6/5/81~_ PARKER RIG NO. 56 860 Oilwell of SE Corner of Section 4,. TGN, R_13_W_ SM DRILL PIPE DESCRIPTION 7" 19.5# 'E' & 'S-135' i12-" ,E' ...... PERMIT NO._ ~l-~h SERIAL NO. 733-70062 TD 7032' ~D v, v~ TVD 6467' DEVIATION-'(BHL)~ -219-7-' at-s 86-0 28' w COMPANY ENGINEER Watson-Boulware ELEVAT'I'~: WATER DEPTH 62' RT TO OCEAN FLOOR 174' RT TO GL ll2' RT TO DRILL DECK 22.07" RT TO PRODUCTION DECK 40.82' APPROVED sIZ~ -WEIGHT CASING & TUBING RECORD "' GRADE DEPTH REMARKS 13 3/8" 61# Butt 0-55 1082' Cmtd w/ 1200 sx "G" w/ additivies -- 13 3/8" Window f/ 380'-460' 9 5/8" 47# Butt N-80 1995' Cmtd w/ 650 sx "G" w/ additivies 7" 29# Butt P-110 to 5887' THREAD- N-80 to 7020' Cmtd w/ 1000 sx "G" w/ additivies 2 7/8- 6.5# BUtt N-80 5598' Dual 'complet-lon Dual Pkr - 4403' 2 318" 416# Butt N-80 4427' -DATE .... INTERVAL ...... E.'T.-D. PERFORATING RECORD REASON Si.ngle Pkr - 5554' PRESENT -CONDITION 5/81 6663-6876' 6886' 6638-6642' 6886' 6896-6900' 6886' 2/84 6270-6310' 6480' Hemlock perfs below cmt retainer Sqz'd w/ 200 sx "G" w/ additives Sqz'd w/ 200 sx "G" w/ additiVes _ Production 58-1 Sd Open 6265-6268 ' 5805-5825' 6480' 6480' Sqz.d. w/ 138 sx "G" w/ additives _ Produc~ib~ 54-5 Sd Open 5675-5770' 6480' 5600-5625' 6480' Production 53-8 Sd Open Production 53-0 Sd Open 5590-5592 ' 6480 ' 5-425--5500' 648'0', $.qzd w/ !05 sx "G" wi addit, iye.s _ _ Production 51-6 Sd Open 5339-5341 ' 52i0-5245' 6480' 64'8b, S.q.zd w/ 180 sx "G" wi additives__ Production 50-3 Sd Open 5005-5025' 6480' Production 48-7 Sd Open 2/84 4999-5001' 6480' 4611-4613 ' 6480 ' 4555--4585' 6480' Sqzd w/ 131 sx "G" w/ additives Sqzd w/ 167 sx "G" wi additives Production C'6' 'sd- ripen 4435-4475' 6480' Production C-5 Sd Open 4428-4430' 6480' Sqzd w/ 140 sx "G" w/ additives INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS WELL HEAD ASSEMBLY TYPE: CASING HEAD: Shaffer Model KD, 12" - 900 w/ 2" Outlets ,-~ CASING SPOOL: CIW 12" 3000psi x 12" 3000psi ..... L _~ TUBING HEAD: CIW 12" ~00~ psi x 7 1/16" 5000 psi TUBING HANGER: CIU 2 3/8" Dual DCB RECEIVFD TUBING HEAD TOP: MASTER VALVES: CHRISTMAS TREE TOP CONN: NOV ! Alaska 04 & Gas Co.ns. Cnmm!_e_e.lO,.' .. Anchorage UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO,' A-9 RD WO FIELD TRADING BAY FIELD DATE ETD ~MONOPOD PLATFORM .' .A-9 RD WO (UOCO) AFE #331001 U.O.' 50.0% DETAILS. OF OPERATIONS, DESCRIPTIONS & RESULTS ~ , , 2/04/84 6886' ETD 9 5/8"i995' 7" 7020' FIW DAILY COST:' $ 23,287 ACC COST: $ 23,287 AFE AMOUNT: $1,120,000 RU & FILL ANNULUS W/ FIW. PUMPED 48 BBLS OF FIW ~ 700 PSI. PRESSURE BLED TO ZERO IMMEDIATELY. INSTALL X-O FLANGE ON RISER. RU WL (MEYERS). PULL SSSV, RD (MEYERS) PUMPED 10.6 BBLS FIW TO FILL TBG. PUMPED 90 BBLS (CAC03 20#/BBL) (l#/BBL XC) INTO PERFORATIONS. PRESS INCREASED 700-1000 PSI WHILE PUMPING. ND TREE, NU BORE. .2 D 2/09/84 6886' ETD 9 9/8" 1999' 7" 7020' FIW DAILY COST: $ 19,017 ACC COST: $ 42,304 NU & CHANGE TO 2 7/8" & 3 1/2" RAMS. REPAIR & REPLACE BURNED UP KOOMEY CONTROL LINES. GENERAL RU. TESTING BORE'S. ROORBOY DEGASSER FROZE UP W/ ICE & SAND. THAWED OUT W/ STEAM. AFE AMOUNT: $1,120,000 3 D 2106/84 6886' ETD 9 9/8" 1999' 7" 7020' flW DAILY COST: $ 25,804 ACC COST: $ 68,108 AFE AMOUNT: $1,120,000 TEST BORE. POOH WITH SINGLE 2 7/8" COMPLETION ASSY. CHANGE PIPE RAMS TO 3 1/2". RIH WITH 6" BIT AND 7" CSG SCRAPER AND TAG PERM PKR 8 6613' DPM. POOH WITH 3 1/2" D.P. 4 D 2/07/84 DAILY COST: ACC COST: AFE'AMOUNT: 6950' ETD (CMT RET) 9 9/8" 1995' 7" 7020' FIW $ 38,617 $ 106,725 $1,120,000 SET EZ DRILL RET AT 6590' DPM. TEMP REP POWER.LINE TO HOWCO PUMP. UNABLE TO GET TEST ON BORE. POOH W/ DP. FIX LEAKS IN DCB SPOOL & TEST BORE. BLINDS WOULDN'T TEST BUT PIPE RAMS & HYDRIL TESTED OK. RIH W/ DP. STAB INTO CMT RET $ 6990'. PRESS UP TO 4900 PSI ON SURFACE W/ NO BREAKDOWN OR BLEED OFF. RESTAB W/O SUCCESS. ABANDON HEMLOCK ZONE W/ 39 CU FT OF CMT ON TOP .OF CMT RET ("G", .75% CFR-2, .4% HALID 22-A, 1% CACL2) CIP $ 10:00 PM 2/07/84. POOH W/ DP. NOTHING WRONG W/ STINGER. BLIND RAMS STILL WON'T TEST. RU TO LAY DOWN 2 7/8" TBG. UNION OIL COMPANY OF CALIFORNIA WELLRECORD SHEET D PAGE NO. LEASE TRADING BAY STATE 'WELL NO., A-9 RD WO FIELD TRADING BAY FIELD DATE ETD D DAILY COST: ACC COST: AFE AMOUNT: 6550' ETD '(CMT RET) 9 5/8" 1995' 7" 7020' FIW $ 20,881 $ 127,606 $1,120,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS FINNISHED LAYING DOWN 2 7/8" TBG.' REPAIR BLIND RAMS IN SCHAFFER DBL GATE. FOUND SEVERE WEAR. CLEARANCES BETWEEN SEAT AND RAMP OVER SPECIFICATIONS. REPAIR LEAK IN BRAKE COOLING WATER SYSTEM. INSTALL PERMANENT LEAD AND CIRCUIT BREAKER TO HOWCO UNIT. 6 D 2/09/84 DAILY COST: ACC COST: AFE AMOUNT: 7 D 2/10/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' ETD (CMT PLUG) 9 5/8" 1995' ~7" 7020'-- FIW & KCL 68 PCF $ 32,157 $ 159,763' $1,120,000 6480' TD (CMT PLUG) ' 5290' ETD (CMT RET) 9 5/8" C. 1995' ; 7" C. 7020' FIW & KCL 68 PCF $ 84,370 $ 244,133 $1,120,000 TEST BORE TO 3000 PSI, OK. CLEAN OUT CMT F/ 6409-6480'. WT UP SYSTEM TO 68 RCF W/ KCL & FIW. RIH W/ WL & PERFORATE Fl 6266-6268' W/ 4 HPF. POOH. RIH W/ GUAGE RING TO 6240'. POOH. RIH W/ CMT RET AND SET $ 6228' DIL (6230' CBL) ON WL. RIH W/ DP TAG CMT RET $ 6236 DPM. TEST ALL LINES TO 6000 PSI. BROKE DOWN PERFS W/ 3200 PSI. MIXED 170 SXS, "G", .75% CFR-2, .4% HALID 22A, AND 1% CACL2. DISPLACED 138 SXS BEHIND PERFS W/ FINAL PUMPING PRESSURE OF 4175 PSI. SQZ JOB HELD 2700 PSI W/ PUMPS OFF AFTER 3 MIN. CMT IN PLACE $ 10:42 AM, 2/10/84. PERFORATED F/ 5590-5592' W/ 2-1/2" HPF. RIH W/ CMT RET ON DP AND SET $ 5554'. TEST ALL LINES. BROKE DOWN PERFS W/ 3100 PSI. MIXED 180 SXS SAME SLURRY AS ABOVE. DISPLACED 105 SXS BEHIND PERFS W/ FINAL PUMPING PRESSURE OF 4250 PSI. SQZ 0OB HELD 2250 PSI W/ PUMPS OFF AFTER 3 MIN. CMT IN PLACE $ 7:25 PM 2/10/84. POOH W/ DP. RU TO PERFORATE NEXT ZONE FOR ISOLATION. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO.. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD 8D 2/11/84 DAILY COST: ACC COST: 6480' TD '(CMT PLUG~; 4578' ETD (CMT RET) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 86,106 $ 330,239 AFE.AMOUNT: $1,120,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS PERFORATED F/ 5339-5341' DIL (5340-5342' CBL) W/ 4-1/2" HOLES 2 HPF. RIH W/ CMT RET ON DP AND SET $ 5290'. TESTED ALL LINES~TO 5000 PSI. BROKE DOWN PERFS W/ 3000 PSI. MIXED 200 SXS CLASS "G", .75% CFR-2, .4% HALID 22-A, AND 1% CACL2. DISPLACED 180 SXS CMT BEHIND RERFS W/ FINAL PUMPING PRESS OF 3250 PSI. SQZ HELD 2500 PSI W/ PUMPS OFF AFTER 4 MIN. CIP $ 4:55 AM 2/11/84. PERFORATED F/ 4999-5001' DIL (5000-5002' CBL) W/ 4-1/2" HOLES 2 HRF. RIH W/ CMT RET ON DP AND SET 8 4951'. TEST ALL LINES TO 5000 PSI. BROKE DOWN PERFS W/ 3100 PSI. MIXED 150 SXS SAME SLURRY AS ABOVE. DISPLACED 131 SXS CMT BEHIND PERFS W/ FINAL PUMPING PRESSURE OF 3550 PSI. SQZ HELD 2300 PSI W/ RUMPS OFF AFTER 4 MIN. CIP ~ 11:22 AM 2/11/84. PERFORATED F/ 4615-4617' DIL (4617-4619' CBL) W/ 4-1/2" HOLES 2 HRF. RIH W/ CMT RET ON DR AND SET ~ 4578'. TEST ALL LINES TO 5000 PSI. .BROKE DOWN PERFS W/ 2900 PSI. MIXED 160 SXS SAME SLURRY AS ABOVE. DISPLACED 142 SXS CMT BEHIND RERFS W/ FINAL PUMPING PRESSURE OF 3300 PSI. SQZ HELD 2200 PSI W/ RUMPS OFF AFTER 3 MIN. CIP · 6:04 PM 2/11/84. PERFORATED F/ 4428-4430' DIL (4430-4432' CBL). RIH W/ CMT RET ON DP. 9 D 2/12/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 4575' ETD (CMT) _. 9 5/8"' C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 32,901 $ 363,140 $1,120,000 SET CMT RET $ 4395' ON DP. TESTED ALL LINES TO 5000 PSI. BROKE DOWN PERFS W/ 2900 PSI. MIXED 160 SXS CLASS "G", .75% CFR-2, .4% HALAD 22-A 1% CACL2. DISPLACED 140 SXS CMT BEHIND PERFS W/ FINAL PUMPING PRESSURE OF 3100 PSI. SQZ HELD 1600 PSI W/ PUMPS OFF AFTER 3 MIN. CIP ~ 1:20 AM 2/12/84. POOH W/ DP. CHANGE OUT DCB SPOOL. INSTALL CIW 13 5/8" (3000) X 7 1/16" (5000) DCB SPOOL & "XO" TO RISER. RIH W/ 6" MILL AND CO TO 4575'. 10 D 2/13/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 24,172 $ 387,312 $1,120,000 POOH W/ 6" MILL. RIH W/ 6" BlT. DRILL ON CMT RET $ 4578'. DRILL UP SAME. CO SOFT CMT F/ 4579-4594'. CO FIRM CMT F/ 4594- 4655'. RIH TO 4951'. DRILL ON CMT RET. TRIP FOR NEW BIT. DRILL UP RET ~ 4951'. CO SOFT CMT F/ 4952-5016'. RIH AND TAG CMT ~ 5266'. CO CMT TO 5290'. DRILL ON CMT RET $ 5290'. CHASE RET TO 5306'. DRILL UP SAME. CO HARD CMT F/ 5306-5358'. CO STRINGERS F/ 5358-5532'. CO FIRM CMT F/ 5532-5554'. DRILL ON CMT RET e 5554. TRIP FOR NEW BIT. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO., A-9 RD WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS ll D 2/14/84 6480' TD (CMT PLUG) RIH'W/ NEW 8IT. DRILL ON CMT RET $ 5554'. DAILY COST: ACC COST: AFEAMOUNT: 9 5/8" C. 1995' 7" C. 7020' FIW &KCL 68 PCF $ 21,133 $ 408,445 $1,120'000 NO CMT F/ 5555-5559'. HARD CMT F/ 5559- 5602'. STRINGERS TO 5643'. RIH TO 6236'. DRILL ON CMT RET~ CO TO 6480'. POOH. PU 6" BIT & 7" SCRAPER. RIH. CIRC & POOH. RU DRESSER ATLAS TO RUN GR, CBL, CLL. 12 D 2/15/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 9 5/8" C.' 1995' 7" C. 7020' FIW & KCL 68 PCF $ 54,139 $ 462,584 $1,120,000 COMPLETE CBL, GR, CLL. RUN DRY TEST W/ lO00 PSI BHP ON THE "D" & "E" ZONES. NO ENTRY. RUN DRY TEST W/ 1000 PSI BHP ON THE "C" ZONE. NO ENTRY. RU TO RESQUEEZE BELOW THE C-6 SAND. SET CMT RET $ 4653' DIL ON WL. PERFORATE F/ 4611-4613' DIL. SET CMT RET 8 4574' DPM. TEST LINES TO 5000 PSI. STING INTO CMT RET AND PUMP INTO FORMATION 8 3200 PSI 8 5 CFM. PUMPED CMT. WHEN CMT ENTERED PERFORATIONS THE PRESSURE INCREASED TO 6500 PSI IMMEDIATELY AND BURST CMT LINE ON THE SURFACE. CHANGE OVER 'CMT LINES, (+ 5 MINS) AND REVERSED OUT CMT. POOH W/ D.~. LAY DOWN STINGER. NO VISIBLE DAMAGE. 13 D 2/16/84 DAILY COST: ACC COST: AFE AMOUNT: 6480' TD (CMT PLUG) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF $ 27,911 $ 490,495 $1,120,000 RIH W/ 6" MILL. TAGGED AND MILLED ON CMT RET AND CMT ~ 4578'. PUSH RET TO 4661' DPM. POOH. PU BIT & SCRAPER & RIH TO 4661' DPM. CIRC BTMS UP. POOH. RATTLE DP NO SCALE. RIH TO 4653' DIL W/ OUNK BASKET ON WL. POOH. PERFORATE 4611-4613' DIL. RIH W/ CMT RET ON DP AND SET $ 4569' DPM. TEST SURFACE LINES TO 5000 PSI. STING INTO RET AND PRESS UP TO 6000 PSI W/ NO BREAK DOWN. FOUND ~FINES IN MUD PLUGGING RETAINER. DUMPED PITS & DISPLACED HOLE W/ FIW. RU CMT LINES. BROKE DOWN FORMATION $ 3000 PSI & 23 CFM. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD 1.4 'D "2~'17/8~ 4480' 'i;D '"(C~T PLUG)' 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF DAILY COST': $ 35,660 ACC COST: $ 526,155 AFE AMOUNT: $1,120,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS FINISHED CLEANING MUD SYSTEM Y'~NKs.' ~u~P~D .... 167 .SXS CMT BELOW CMT RET ~ 4569' DPM (FIW, .75% CFR-2, .4% HALAD 22A, 1% CACL2) W/ FINAL PUMPING RATE OF 5 CFM ~ 2500 PSI. SQZ JOB HELD 2000 PSI W/ PUMPS OFF AFTER 5 MIN. CIP ~ 3:00 AM, 2/17/84. POOH W/ DP. RIH W/ 6" BIT. CO CMT F/ 4566-4569'. DRL UP CMT RET ~ 4569'. CO CMT F/ 4572-4640". STRINGERS TO 4660'. DRL ON CMT RET ~ 4661-4662'. POOH W/ DP. PU 6" SUNK MILL & RIH. 15 D 2/18/84 6477' TD (CMT PLUG W/ SUNK ON TDP) 9 5/8" C. 1995' 7" C. 7020' FIW & KCL 68 PCF DAILY COST: $ 26',158 ACC COST: $ 552,313 AFE AMOUNT: $1,120,000 RIH & MILL ON CMT RET ~ 4662'. RIH TO 6477" ETD. SWEEP HOLE W/ VISCOUS PILL. POOH'. PU 6" BIT & 7" SCRAPER. RIH TO 6477'. CIRC HOLE CLEAN. POOH. PU TEST ASSY & RIH. LOAD DP W/ 1050 PSI GAS. SET RTTS ~ 4375'. BLEED OFF GAS. RUN DRY TEST ON "C" ZONE SQZ PERFS.. 19 BBLS/ DAY OF FLUID ENTRY. TEST OK. FILL HOLE & REVERSE OUT. RIG DOWN SURFACE LINES. :16 D 2/19/84 4477' TD (CMT PLUG W/ 'JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' PERF PILL POOh. LAY DOWN RTTS. RIH OPEN ENDED TO 6477'. MIX 77 PCF SAFE LINK COMPLETION SYSTEM AND BALANCE F/ 6477-3000'. POOH. TEST BOPE. RU DRESSER ATLAS. RIH W/ 20', 5" CSG GUN. GUN STOPPED ~ 4611' (BTM OF DAILYCOST: ACC COST: AFE AMOUNT: (77 PCF f/ 6477-3000') GUN) POOH. RIH W/ 10' 5" CSG GUN GUN ' , · (68 PCF 'f/ 3000'-SURFACE) STOPPED 4611'. POOH. RIH W/ 6" TAPERED MILL AND REAM THRU TIGHT SPOT ~ 4613-4615' $ 42,953 DPM. TORQUE VARIED F/ 200-400 AMPS. MILLED $ 595,266 ."' TIGHT SPOT UNTIL TORQUE FELL OFF TO NORMAL. POOH. RU DRESSER ATLAS. RIH W/ 20', 5" CSG $1,120,000 GUN. 17 D 2/20/84 6477' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 68 PCF DAILY COST: $ 35,820 ACC COST: $ 631,086 AFE AMOUNT: $1,120,000 RIH W/ 20', 5" CSG GUN. GUN STOPPED AGAIN 8 4611' WLM. POOH· PU 4" GUN & RIH TO 6314' WLM W/ NO PROBLEMS. POOH. RU DIALOG MIN I.D. CALIPER TOOL· LOG F/ 5700' - SURFACE. LOG SHOWS I.D. OF 7" CSG TO BE AS SMALL AS 5 7/8" IN PLACES. PU 10', 4" CSG GUN & RIH. PERFORATE F/ 6310-6300' DIL. TAGGED FILL 8 6358' WLM. POOH W/ WL. PU 6" BIT & 7" SCRAPER & RIH. TAG FILL 8 6367' DRM. CIRC THRU FILL TO 6477' TD. FILL CONSISTED OF SALT PARTICLES F/ RERF PILL· UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD lSD :'2/21/84 6477'~'TD.. DETAILS OF. OPERATIONS, DESCRIPTIONS & RESULTS CIRC ]WELL:: CLEAN. 'DUMP & CLEAN MUD SYSTEM. · DAILY COST: ACC COST: AFE AMOUNT: (cMT,,.PLUG'W/ SUNKiON TOP) ~ MIX'400 BBES OF SATURATED NACL BRINE. MIX 9 5/8":C,~1995' '"~! ~ 150 BBLS SAFE LI'NKRERFORATING PILL. SPOT 7" C. 7020',D : PERFORATING RILLs!F/ 6477 - +2700'. POOH W/ (74 PCF SAT BRINE)' " DP. RIH W/ WL AND PERFORAT~F/ 5310-5300' (77 PCF PERFORATING RIJ_L)~ DIL W/ 4" CSG GUNS, 4 HPF, 120° PHASING. NO · ." · · ' · ~FILL .ON BTM OF HOLE. $ 48,640 $ 679,726 , $1,120,000 19 D 2/22/84 6477' TD. PERFORATEDTHE FOLLOWING INTERVALS: · .. :. (CMT PLUG W/OUNK ON TOP) 6270-6300', 5805-5825' 5675-5770' 9 5/8" C 1995' 5600'5625' 5485-5500' W/ 4" CSG GUNS, · , 7" C. 7020' 8 HPF, 120° PHASING. (74 PCF SAT' 8PINE) (77 PCF PERFORATING PILL)- DAILY COST: $ 30,530, ACC COST: $ 710,256 AFE AMOUNT: $1,120,000 20 D 2/23/84 6477'li'TD PERFORATEDF/ 5465-5485' DIL, TOOK 10 BBL (CMT PLUG W/ SUNK ON TOP):GAIN WHILE PULLING WL OUT OF HOLE, SHUT 9 5/8" C' 1995' 7" C' 7020' 90 PCF (SURFACE-4350' 77 PCF (4350-6477') DAILY COST: $ 91,281 ACC COST: $ 801,537 AFE AMOUNT: $1,120'000 WELL IN ~ 1:50 AM. CSG PRESS 320 PSI. STRIP IN HOLE W/ CMT RET ON WL. SET CMT RET ~ 4350' CBL. BLED PRESSURE OFF ~ SURFACE. RIH W/ STINGER ON DP. BUILD SAFE LINK COMPLETION SYSTEM TO 90 PCF. STAB INTO RET AND CHECK FOR FLOW. ZERO PSI ON DP'~ SURFACE. POOH W/ DP. RIH W/ 6" BIT. BUILD SURFACE VOLUME TO 90 PCF. 21D 2/24/84 6466' TD (CMT PLUG W/ OUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 88 PCF DAILY COST: $ 33,075 ACC COST: $ 834,612 RIH W/ 6" BIT. DRILL UP CMT RET ® 4350' CBL (4363' DPM). CIRCULATE AND CHASE CMT RET TO 6466' DPM. BUILD SALT COMPLETION SYSTEM TO 88 PCF. PERFORATED THE FOLLOWING INTERVALS THROUGH OPEN ENDED DP SET ABOVE EACH SAND. PERFORATE W/ 2 1/8" CARRIERS, 4 HPF, 0° PHASING; 5425-5429' (51-6 SD) DIL, 5210-5214' (50-3 SD) OIL. AFE AMOUNT: $1,120,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD : 22 D 2/25/84 6466' TD (CMT PLUG W/ JUNK ON, TOP)~ 9 5/8" C. 1995' 7" C. 7020' ' 87 PCF DAILY COST: $ 33,412 ACC COST: $ 868,024 AFE AMOUNT: $1,120,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS CONT'INUE PERFORATING` THE FOLLOWING INTERVALS THROUGH OPEN ENDED DP W/ 2 1/8" CARRIERS, 4.HRF, 0° PHASING; 5005-5009' (48-7 SD).DIL, 4555-4559' (C-6 SD) DIL, 4435-4439' (C-5 SD) DIL. OBSERVED NO FLOW INTO WELLBORE. POOH W/ DP. PERFORATED THE FOLLOWING INTERVALS W/ 4" CSG GUNS, 4 HRF, 120° PHASING TO A FINAL SHOT DENSITY OF 8 HPF; 5485-5425' (51-6 SD) DIL, 5230-5245' (50-3 SD) DIL. TOOK 11 BBL GAIN IN FIVE HOURS. RIH W/ DP. 23 D 2/26/84 6466' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 87 PCF DAILY COST: $ 44,886 ACC COST: $ 912,910 AFE AMOUNT: $1,120,000 RIH TO 6310'. CIRC FLUID. HAD SOME 83 PCF COMP FLUID TO SURFACE. BUILD WT TO 88 PCF. POOH W/ DP. PERFORATE THE FOLLOWING INTERVALS W/ 4" CSG GUNS, 4 HPF, 120° PHASING TO A FINAL SHOT DENSITY OF 8 HPF; 5210-5230' (50-3 SD) DIL, 5005-5025' (48-7SD) DIL, 4555-4585' (C-6 SD) DIL, 4435-4475' (C-5 SD) DIL. RIH W/ 6" BIT & 7" CSG SCRAPER ON DP. TAG FILL $ 6226' DPM. CO SALT & PERFORATING DEBRIS TO 6466'. 24 D 2/27/84 6466' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 87 PCF DAILY COST: $ 25,177 ACC COST: $ 938,087 AFE AMOUNT: $1,120,000 CO FILL (SALT AND PERFORATING DEBRIS). POOH W/ DP. RIH W/ 5.782" GAUGE RING AND JUNK BASKET ON WL TO 6400'. POOH W/ WL. RIH W/ BAKER MODEL "D" PERM PKR AND SET $ 5544' DIL ON WL. POOH W/ WL. RIH W/ BAKER SEAL ASSY ON DP & TAG PKR 8 5557' DPM. TEST PKR TO 400 PSI (OK). POOH LAYING DOWN DP. RU TO RUN DUAL 2 3/8" COMPLETION ASSY. 25 D 2/28/84 6466' TD (CMT PLUG W/ JUNK ON TOP) 9 5/8" C. 1995' 7" C. 7020' 87 PCF DAILY COST: ACC COST: $ 416,026 $1,354,113 AFE AMOUNT: $1,120,000 RUN DUAL 2 3/8" COMP ASSY. SPACE OUT & LAND TBG. PULL DUMMY SSSV IN SS. RUN "N" TEST PLUG IN SS TO "XN" BELOW HYD PKR. ATTEMPT TO SET HYD RKR W/O SUCCESS. CHANGE OUT "N" TEST PLUG & RIH & SET IN "XN". SET DUAL HYD RKR. POOH W/ TEST PLUG. SET SSSV'S IN LS & SS. SET BPV'S IN LS & SS. NIPPLE DOWN BOPE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD WO FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 26 D 2/29/84 6466' TD DAILY COST: ACC COST: ND BORE.. NU DUAL 2 3/8" X-MAS TREE & TSTD TO (CMT PLUG W/ OUNK ONTOR) 5000 PSI. RULL'BPV'S. PULL SSSV IN SS. OPEN 9 5/8" C. 1995' "XA" SLEEVE ABOVE DUAL HYD PKR. SET "N" PLUG 7" C. 7020' $ 26,294 $1,380,407. IN TAIL~OF SS. DISPLACE ANNULUS W/ CLEAN FIW. CLEAN MUD PITS. POOH W/ "N" PLUG. CLOSE "XA" SLEEVE. INSTALL SSSV IN SS. RELEASE CREWS F/ AFE # 331001 8 24:00 HRS, 2/29/84. AFE AMOUNT: $1,120,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD FIELD TRADING BAY DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS .]TS DESCRIPTION -Monopod Conductor #16 20" DRIVE PIPE LENGTH BTM 179.0 179.0' TOP 0.0' .]TS ¸25 13 3/8, CASING DETAIL DESCRIPTION Baker Flexi-flow Shoe 13 3/8" 61#, 0-55 Armco Seal-Lock Baker Flexi-flow COllar 13 3/8" 61#,.]-55 Armco Seal-Lock ~Shaf'fer Fin Joint · Landed below Rotary Table LENGTH BTM 2.10' 1082.00' 38.82' 1079.10' 1.90' 1041.08' 990,76' 1039.18' 8.42' 48.42' 40.00' 40.00' TOP 1079.10' 1041.08' 1039.18' 48.42' 40.00' 45 Float Shoe 9 5/8" 47# N-80 Buttress Float Collar 9 5/8" 47# N-80 Buttress Landed below zero ? 5/8",CASING DETAIL 1.60' 1995.00' 45.70' 1993.40' 1.56' 1947.70' 1908.14' 1946.14' 38.00' 38.00' 1993.40' 1947.70' 1946.14' 38.00' 26 1 145 1 Howco Float Shoe 7" 29# P-il0 Howco Float Collar 7" 29# P-110 7" 29# N-80 Pup St 7" 29# N-80 Cut off 7" 29# N-80 Landed Below ZerO 7" CASING DETAIL 1.88' 7020.20' 39.76' 7018.32' 1.70' 6978.56' , 1089.63' 6976.86' 20.28' 5887.23' 5798.34' 5866.95' 31.41' 68.61' 3Y.20' 37.20' 7018.32' 6978.56' 6976.86' 5887.23' 5866.95' 68.61' 37.20' LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. WELL NO. A-9 RD FIELD TRADING BAY DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS TOP BTM SHORT STRING TUBING DETAIL LENGTH STS DESCRIPTION 4427.89' 4427.44' 4426.74'' 4411~69'~ 4411.29' 4408.73' 4405,33' 4403.08' 4402.65' 4375.05' 4372.38' 4371.68' 4342.23' 4336.43' 4335.73' 4303.42' 4297.32' 4049.37' 4043.32' 3703.18' 3693.38' 3535.04' 3529.24' 4428.5,0 ,. :' ,'., :' 4427.89' 4427.44' 4426.74'! 4411.69' 4411.29" 4408.73' 4405.33' 4403.08' 4402.65' 4375.05' 4372.38' 4371.68' 4342.23' 4336.43' 4335.73' 4303.42' 4297.32' 4049.37' 4043.32' 3703.18' 3693.38' 3535.04' .61' .45' .70' 15.05' .40' 2.56' 3.40' 2.25' .43' 27.60' 2.67' .70' 29.45' 5.80' .70' 32.31 ' 6.10' 247 · 95 ' 6.05' 340.14' 9.80'' 158.34' 5.80' ll Baker Wireline Entry Guide Otis 2 3/8" X-N Nipple ' 2'3/8" Butt Coupling 2 318" Butt 4.6# puP Ot 2 3/8" Butt Pin x 2 3/8 10 Rnd Box X-Over Tail Below Packer Packer Body to Packoff PaCker Body from Packoff Baker Left Hand Safety Sub Tack Welded to Pkr Body 2 3/8" 4.6# Butt Otis 2 3/8" X-N Nipple 2 3/8" Butt Coupling 2 3/8" 4.6# Butt 2 3/8" GLM 2 3/8" Butt Coupling 2 3/8" 4.6# Butt 2 3/8" Butt Pup St 2 3/8" 4.6# Butt 2 3/8" Butt Pup St 2 3/8" 4.6# Butt 2 3/8" Butt Pup Jt 2 3/8" 4.6# Butt 2 3/8" GLM LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. WELL NO. A-9 RD FIELD TRADING BAY DATE ETD DETAILS:OF OPERATIONS, DESCRIPTIONS & RESULTS ,SHOR.T~STRING TUBING DETAIL TOP. BTM LENGTH STS DESCRIPTION 3528.54' 3064.1.4" 3058'09' 2313.90" 2307.77' 2180.96' 2175.16' 2174.46' 337.09' 335.39' 334.69' 53.05' 38.8i' 37.92' 37.i3' 36.i3' 0 3529.24 3528.54' 3064.14' 3058.09' 2313.90' 2307.77' 2180.96 ' 2175.16' 2174.46' 337.09 ' 335.39' 334.69' 53.05' 38.81' 37.92' 37.13' 36.13' .70' 464.40' 6.05' 744.19' 6.13' 126.81t 5.80' .70' 1837.57' 1.70' .70' 281.64' 14.24' .89' .79 1.00' 36.13' 15 24 r4 59 '2 3/8" Butt Coupling 2 3/8" 4.6# Butt 2 3/8" Butt Pup St 2 3/8" 4.6# Butt 2 3/8" Butt Pup Ot ~2 3/8" 4.6# Butt 2 3/8" Butt GLM 2 3/8" Butt Coupling 2~3/8'' 4.6# Butt Otis 2 3/8" XEL Ball Valve 2 3/8" Butt Coupling 2 3/8" 4.6# Butt 2 3/8" Butt Pup St 2 3/8" Butt x 2 3/8" 8 Rnd X-Over Tubing Hanger Standoff DCB to Rig Floor LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE.NO. WELL NO. A-9 RD FIELD TRADING BAY DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS " ~LONG STRING TUBING DETAIL TOP ,BTM LENGTH _ JTS DESCRIPTION -. 5597.56' 5582.44' 5581.99' ' 5581.29' 5566.14' 5565.38' 5554.78' 5553.73' 5552.97' 5542.92' 5536.79' 5530.66' 5528.19' 5527.49' 5517.41' 5517.11' 5516.41' 5515.21' 5430.21' 5390.33' 5388.53' 5263.80' 5261.72' 5260.52' 5598.26' .70" 5597.56' 15.12' ~5582.44' .45' 5581.99' .70' 1'5581.29' 15.15' 5566.14' .76' 5565.38' 10.60' 5554.78' 1.05' 5553.73' .76' 5552.97' 10.05' 5542.92' 6.13' 5536.79' 6.13' 5530.66' 2.47' 5528.19' .70' 5527.49' 10.08' 5517.41' .30' 5517.11' .70 5516.41' 1.20' 5515.21' 85.00' 5430.21' 39.88' 5390.33' 1.80' 5388.53' 124.73' 5263.80' 2.08' 5261.72' 1.20' Mule Shoe 2 3/8" Butt Pup Ot Otis2 3/8" "X" Nipple 2 3/8 Butt Coupling 2 3/8" Butt Pup St 2 3/8" But X 2 7/8" Butt X-Over Seal Assembly for Baker Model "D" Packer Locator Sub 2 7/8" Butt4 X 2 3/8" Butt X-Over 2 3/8" Butt Pup St 2 3/8" Butt Pup St 2 3/8" Butt Pup Ot Otis 2 3/8" "X-A" Nipple 2 3/8" Butt Coupling 2 3/8" Butt Pup Ot 2 3/8" Butt X 2 7/8" Butt X-Over 2 7/8" Butt Coupling 2 7/8" Butt X 2 7/8" Hydril X-Over 2 7/8" Hydril Blast $oints 2 7/8" 6.5# Hydril (Blank above Carbide Rings) 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" 6.5# Butt 2 7/8" Butt Pup'~t 2 7/8" Butt X 2 7/8" Hydril X-Over LEASE TRADING BAY STATE UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D RAGE NO. WELL NO. A-9 RD FIELD TRADING BAY DATE ETD DETAILS OF· OPERATIONS'DESCRIRTIONS & RESULTS ~i~: '·~-:·!~LONG STRING TUBING DETAIL TOP , BTM .." LENGTH· STS " ' ' DESCRIPTION 5215'52' 5197.'42' 5t95.62'. 5040.46'· 50319.26'i: ' 5009.26' 5007,38'.' 5005.58' 4612.82' 4606.72' 4600.69' 4599.49' 4559.49' 4536.19' 4534.52' 4503.32' 4493.31' 4491.06' 4489.86' 4439.86' 4426.33' 5260.52' 5215.52' 5197.42' 5195.62' 5040.46' 5039.26'~ 5009.26' 5007.38' 5005.58' 4612.82' 4606.72' 4600.49' 4599.49' 4559.49' 4536.19' 4534.52' 4503.32' 4493.31' 4491.06' 4489.86' 4439.86' 45.00' 18.10' 1.80' 155.16' 1.20' 30.00' 1.88' 1.80' 392'76' 6.10' 6.03' 1.20' 40.00' 23.30' 1.67' 31.20' 10.01 ' 2.25' 1.20' 50 · O0 ' 13.53' -5 13 '2 7/8" Hydril Blast Sts ~'2 7/8" 6.5# Hydril (Blank above Carbide Rings) 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" 6.5# Butt 2 7/8" Butt'X 2.7/8" Hydrill X-Over 2 7/8" Hydril Blast Ont 2 7/8" 6.5# Hydril (Blank above Carbide Rings) 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" 6.5# Butt 2 7/8" 6.5# Butt Pup St 2 7/8" 6.5# Butt Pup St 2 7/8" Butt X 2 7/8" Hydril X-Over 2 7/8" Hydril Blast Jt 2 7/8" 6.5# Hydril (Blank above Carbide Rings) 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" 6.5# Butt 2 7/8" 6.5# Butt Pup Ot 2 7/8" 6.51; Butt Pup Ot 2 7/8" Butt X 2 7/8" Hydril X-Over 2 7/8" Hydril Blast ant 2 7/8" 6.5# Hydril (Blank above Carbide Rings) UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD FIELD TRADING BAY DATE ETD ' ~ . DETAILS OF OPERATIONS' DESCRIPTIONS & RESULTS ..... : ~ ' ~ '~"'~" ' LONG?STRING TUBING DETAIL · TOP BTM ~,. LENGTH JTS DESCRIPTION 4424.56' '4426.33' 1.77' 4424.16' 4424.56' .40' 4423.46' 4424.16' .70' 4420.88' 4423.46' 2.58' 4420.18' 4420.88' .70' 4410.45' 4420.18' 9.73 · . 4410.05' .4410.45' .40' 4408.73' 4410.05' 1.32' 4405.33' 4408.73' 3.40' 4403.23' 4405.33' 2.10' 4400.91' ' 4403.23' 2.32' 4400.31' 4400.91' .60' 4368.29' 4.400.31' 32.03' 4365.74' 4368.29' 2.55' 4365.04' 4365.74' .70' '4337.25' 4365.04' 27.79' 4331.45' 4337.25' 5.80' 4330.75' 4331.45' .70' 3701.02' 4330.75' 629.73' 3695.22' 3701.02' 5.80' 3694.52' 3695.22' .70' 3569.59' 3694.52' 124.93' 3565.96' 3569.59' 3.63' 3536.16' 3565.96' 29.80' 3530.01' 3536.16' 6.15' 2O 2 7/8" Hydril X 2 7/8" Butt'X-Over 2 7/8" Hydril X 2 7/8" Butt X-Over 2 7/8" Butt Coupling 2 3/8" Otis "XA" Nipple 2 3/8" Butt Coupling 2 3/8" 4.6# Butt Pup St 2 3/8" Butt X 2 3/8" 10 Rnd X-Over Long String Tail Below Packer Body Packer Body Below Packoff Packer Body Above Packoff Sub above Packer 2 3/8" 10 Rnd X 2 3/8" Butt X-Over 2 3/8" 4.6# Butt 2 3/8" Otis "XA" Nipple 2 3/8" Butt Coupling 2 3/8" 4.6" Butt GLM 2 3/8" Butt Coupling 2 3/8" 4.6# Butt GLM 2 3/8" Butt Coupling 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup Ot 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup Ot UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY STATE WELL NO. A-9 RD FIELD TRADING BAY DATE ~TD DETAILS OF OPERATIONS, DESCRIPTIONS &'RESULTS · , LONG STRING TUBING DETAIL' TOP BTM -- . 2212.62' 3530.01' 2206.82' 2212.62' 2206.12' 2206.82" 2141.81' 2206.12' 2135.69' 2141.81' 1610.15' 2135.69' 1604.05' 1610.15' 1296.31' 1604.05' 1290.19' 1296.31' 710.66' 1290.19' 704.59' 710.66' 433.43' 704.59' 427.39' 433.43' 335'92' 427.39' 334.2~' 335.92' 333.52' 334.22 210.57' 333.52' 204.56' 210.57' 84.86' 204.56' 78.73' 84.86' 46.56' 78.73' 42.15' 46.56' 38.94' 42.15' 37.92' 38.94' 37.13' 37.92' 36.13' 37.13' 0 36.13' LENGTH OTS 1317.39' 42 5.80' .70' 64.31' 2 6.12r 525,44' 17 6.110' 307.74' 10 6.12' 579.53' 19 6.07' 271.16' 9 6.04' 91,47' 3 1,70' .70' 122.95' 4 6.01' 119.70' 4 6.13' 32.17' 1 4.41' 3.12'' 1.02' .79' 1.00' 36.13' DESCRIPTION 2 3/8" 4.6# Butt GLM 2 3/8" Butt Coupling 2 3/8" 4.6# Butt .~ 2 3/8" 4.6# Butt Pup St 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup Ot 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup St 2 3/8" 4.6# Butt 2 3/8" 4.6# Butt Pup St 2 3/8" 4.6# Butt Otis XEL BV Nipplie.#18709-108754 2 3/8" Butt Coupling 2 318" 4.6# Butt 2 3/8" 4.6# Butt Pup 3t 2 3/8" 4.6# Butt 2 318" 4.6# Butt Pup Jt 2 3/8" 4.6# Butt 2 318" 4.6# Butt Pup Jt 2 3/8" 4.6# Butt Pup 3t 2 318" 4.6# Butt Pup Jt Hanger Stand Off DCB to Rig Floor IV- C ZONE C-5 Sd. C-6 Sd. T B.S. A-9R WORKOVER · ' CASING & ABANDONMENT DETAIL 48-7 Sd. 50-3 Sd. 18 ~ Ic- 51-6 Sd. V VI VII - D ZONE DATE 53-O Sd. 53-8 Sd. 54-5 Sd:' E ZONE ,,58-1 Sd. _ HEMLOCK PERFS. I. R.T. ~ O' Il CIW DCB Tubing Hanger 12" 3000# x 7 1/16" 5000# ~ 37.13 · ' III. 13 3/8", 61#, J-55 Butt csg .,~ 1,082'(cmtd w/12COsx) IV. 9 5./8", 47#, N-80 Butt csg. ~ 1,995' (cmt'd w/650 sxs) V. Too of cement plug ~ 6,480' VI. Cement Retainer =m 6,550' w/60 sxs cmt above ret '7" 29# P-110 & N-80 Butt csg O 7,020' (cmtd w/lC00 sxs TUBING DETAIL... .. 2 7/8',6.5~ & 2 3/8' 4.6~,N-80,BUTT. TUBING LONG STRING i · · 8. 9-13. 14. 15. 16. Otis XEL Ball Valve Nipple G 334.22' 2 3/8" Side Pocket G.L.M. @ 2206.82', 3695.22', 4331.45' 2 3/8" Otis "XA" Sleeve ~ 4365.74' Baker Model "A-5" Dual Packer 4403.23' 2 3/8" Otis "XA" Sleeve ~ 4420.88' 2 3/8"x2 7/8" Buttress Cross-over © 4424.16' Carbide Blast Joints, 9) 4439.86-4489.86', 10) 4559.49-4599.49' , 11) 5009.26-5039.26', 12) 5215.52-5260.52, 13) 5430.21-5515.21' 2 7/8"x2 3/8" Buttress Cross-over ~ 5517.11' 2 3/8" Otis "XA" Sleeve ~ 5528.19' 2 3/8"x2 7/8" Buttress Cross-over ~ 5552.97' 17. Locator Sub ~ 5553· 73' 18&19. Baker Moael "D" Packer ~ 5553.73' (5544' D!L) w/lO.6' Seal AsSy ~ 5554.78' 20. 2 7/8" x 2 3/8" Buttress X-over ~ 5565.38' 21. 2.3/8" Otis "X" Nipple ~ 5581.99' 22. Mule Shoe ~ 5597.56' SHORT STRING A. 2 3/8" Otis XEL Ball Value ~ 335.39' B-O. 2 3/8" Side Pocket G.L.M..~ 2175.16' C) 3529.24', D) 4336.43' E. 2 3/8" Otis "XA" Sleeve ~ 4372.38'' F. Baker Model A-5 Dual Packer ~ 4403.08' G. 2 3/8" Otis "XN" Nippl'e @ 4427.44' NOTES: MINIMUM I.D. IN "XA, SLEEVES(1.875") HYDRIL to BUTTRESS CROSSOVER BETWEEN BLAST JOINTS PERFORATION RECORD Date Interval ...__.._.._ 5-81 6663-6876 6638-6642 6896-6900 2-84 ~/6270-6310 ~626~-62~'$ ~5805-5825 ~5675-5770 '~600-5625 ~ ~5590-5592 ~425-55oo ~5339-5341 ~5210-5245 ~4999-5001 ' v4615-4617 ~4555-4585 ~4435-4475 ,×4428-4430 T.B.S. A-9RD WORKOVER WELL SCHEMATIC Condition Hemlock perle below cmt retainer Sqzed w/200 sxs "G" w/additives .Sqzed w/200 sxs "G" w/additives 58-1 sand open for production Sqzed ~or isolation 54-5 sand open for production · 53-8 sand open for production 53-0 sand open for production Sqzed for isolation 51-6 sand open for production Sqzed for isolation 50-3 sand open for production Sqzed ~or isolation Sqzed for isolation C-6 sand opeq for production C-5 sand open for production Sqze~ f. or isolation APP'D. SCALE NONE DATE 318/84 ' COMPLETED ' 2/84 UNION OIL COMPANY OF CALIFORNIA SHEETS SHEET FORM V 247 A 5/56 750 _ Cll II IIC IILLLLII I 111] E;ast 80Ih Anchor;age, AI;askn ggs02 Phone 34g-3541 . Telex: 25-:384 World Leader in Service to the Oil Industry May 14, 1981 Job #4470 Platform Monopod Enclosed please find our Gyro Survey on A-9 Redrill along with our Vertical Section and Horizontal View maps. If any other information is needed please call 349-3541. Thank you for using Scientific Drilling International and please call again. Sincerely Manager RECEIVED APR, 2 8,1982 Oil & G3s Cons, Commission Anchorag9 IMPLETION REPORT : lION OIL OF CALIFORNIA 'ROSCOPIC SURVEY ~DIU$ OF CURVATURE HET.HOD OF COMPUTATION )MPUTED FOR SDC BY FM LINDSEY & ASSOC 14 MAY 81 MONOPOD A-9 REDRILL KB ELEV 101 FT. JOB NO 4470 RECORD OF SURVEY TRUE iAS, DRIFT VERTICAL [PTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 I00 0 0 200 0 0 300 0 0 400 1 30 500 1 30 600 1 45 700 3 '0 800. 4 0 900 3 45 LO00 3 0 0,00 =101.00 N O.OOE 100,00 200,00 300,00 399,98 499'95 599,91 699,82 799,63 .. TOTAL COORDINATES 0.00 $ -0,99 N76,53W ';--~ 0.00 S 99.00 N76.46W 0.00 S 199.00 N76,40W 0,00 S 298.98 N 0.33W 0.95 N 398.95 Nll.26W ..... 3.55 N 498.91 NiO,21W ....... 6.33 N 598,82 N22,88E '10,40 N 698,63 N22,95E ' ="'-"16,02 N 899,40 '798,40 N24,01E 22,22 N 999.23 898,23 N17,O6E ".i'V27.73 N LiO0 3 0 1099.09 998,09 N22,15E L200 2 30 1198,98 1097.98 N18.20E L300 2 0 1298,90 1197,90 N22,33E L400 I 45 1398.85 1297,85 Nll,40E LSO0 1 30 1498,81 1397,81 N26,46E 1600 2 0 1598,76 1497,76 S60,48E [700 2 0 1698.70 1597.70 $46.61W LBO0 5 45 1798.45 1697.45 580.76W 1900 8 0 1897.73 1796.73 586,90W 2000 10 0 1996.49 1895,49 S85,08W ~100 10 0 2094,97 1993,97 S85,50W ~-200 11 BO 2193.21 2092.21 S84.66W 2300 13 0 2290.93 2189.93 S83.86W ~400 15 0 2387.96 2286.96 $82.15W 32.65 N 37.16 N 40.84 N 43.97 N 46,64 N 47.44 N 44,46 N 41,51 N 40,22 N 39,13 N 37.70 N 36.10 N 33.98 N 31,04 N 0,00 W 0,00 W 0,00 W 0.00 W 0,75 W I~. 09 W 1,28 E 3'97 E 6,03 E 7,79 E 9,44 E 10.80 E 11,75 E 12,67 E 15,28 E 15.64 E 9,67 E 2,21 W 17,82 W 35.12 W 53,70 W 74,82 W 98,83 W DOG LEG C L 0 S U R E S SEVERITY DISTANCE ANGLE DEG/IOOFT D M S 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W '1.21 N 38 21 59 W 3.69 N 15 59 29 W 6.52 N 13 42 45 W 10,45 N 6 O 55 W 16.07 N 4 34 17 E 22.57 N 10 8 22 E 28.38 N 12 17 4 E 33,57 N 13 25 21 E 38.34 N 14 15 55 E 42,24 N 14 49 19 E 45,51 N 14 58 7 E 48.33 N 15 12 1 E 49.84 N 17 51 20 E 47,13 N 19 23 12 E 42,62 N 13 7 26 E 40.28 N 3 9 13 W 42,99 N 24 29 0 W 51.53 N 42 58 13 W 64,71 N 56 5 13 W 82.17 N 65 34 7 W 103,59 N 72 33 41 W 0,000 O,000 0.000 0.000 1.501 0.286 0.250 1.253 1.000 0.250 0,750 0,266 0.500 0,500 0,250 0.250 0.513 3.217 3.766 2'i53 2. O1 O. 72 -. 1. O0 1,5'01 2,003 SECTION DISTANCE ) 0.00 0.00 0.00 0.00 0.69 0,79 1.15 0.45 -2.26 -5.33 -7.73 -9,79 -11.72 -13.30 ) -14,44 -15,52 -iS.i? -18.35 -12.21 -0,26 15.37 32,73 51.38 72.58 96.72 ION NON.A-9 RD. GYROSCOPIC SURVEY RECORD OF SURVEY JOB NO ~70. 14 MAY 81 TRUE AS, DRIFT VERTICAL SUB DRIFT PTH ANGLE DEPTH SEA DIREC D M DEG, '500 16 I5 2484,26 2383,26 S84,28W 27,86 N '600 18 0 25?9,82 2478,82 S85,50W 25,24 N !700 20 0 2674,37 2573,37 S86,73W 23,03 N 1800 23 30 2767,24 2666,24 S85.35W 20.47 N 1900 25 0 2858,41 '2757,41 S83,78W '~--'16,59 N ~000 27 30 2948,09 2847,09 S78,70W 9,85 N ~100 28 0 3036,59 2935,59 S77,93W ..... = 0.43 N ~200 28 0 3124,88 3023.88 S77,06W 9. 3 S 3300 28 '0 3213,18 3112.18 S76,18W 20. S ~400 28 30 3301.27 3200.27 S75,43W 32,1119 S 3500 30 0 3388,52 3287,52 S75.86W 44,30,S 3600 31 0 3474,68 3373,68 S76,51W 3700 30 45 3560,51 3459.51 S78,38W 67,56~ 3800.30 0 3646,78 3545.78 S79,20W 3900 30 0 3733,38 3632,38 S80,18W 86,34 %000 30 0 3819-98 3718.98 S81.16W .... 94,44 S %100 30 30 3906,37 3805.37 S83,18W 101.30 S %200 30 0 3992,75 3891,75 584,05W 106.90 S %300 30 0 4079,35 3978,35 S85.08W 111,63 S $400 30 0 4165,96 4064.96 S86.13W 115,46 S TO'TAL COORDINATES CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/IOOFT 125.57 W 154,90 W 187.38 W 224,34 .W 265,22 W 308 , 92~ W 354.51 W 400.35 W 446.02 W 491,91 W 128,62 N 77 29 21 W 156,94 N 80 44 40 W 188,79 N 82 59 27 W 225.27 N 84 47 2 W 265,74 N 86 25 14 W 309,07 N 88 10 19 W 354,51 N 89 55 49 W 400.46 S 88 36 27 W 446,50 S 87 21 24 W 492.96 S 86 15 19 W 541,06 S 85 18 11 W 591,23 S 84 31 27 W 642.18 S 83 57 37 W ,22"W... 692,56 S 83 35 0 W 737'41W '' 742.45 S 83 19 17 W 786,75 w 792,40 S 83 9 16 W 836,65 W 842.77 S 83 5 46 W 886,72 w 893,14 S 83 7 31 W 936,49 W 943,12 S 83 12 6 W 986,35 W 993,08 $ 83 19 22 W 1-261 1,754 2,005 3,507 1,526 2.725 0,528 0.407 0.415 0.528 1.504 1.015 0.548 0.777 0,492 0,492 0.721 0,545 0,517 0,525 0.541 0.504 0,750 0,366 1,000 1,003 0,541 0.549 0,945 %500 29 30 4252,78 4151,78 S85,28W 119.18 S 1035,83 W %600 30 0 4339,59 4238,59 S85,55W 123,14 S 1085,29 W %700 29- 15 4426,52 4325,52 S85,55W 126,98 S 1134.57 W %800 29 30 4513,66 4412.66 S86,65W 130.31S 1183,51W %900 29 0 4600,91 4499.91 N89,66W 131.60 S 1232.35 W 5000 30 0 4687,95 4586,95 N89.35W 131.18 S 1281,59 W 5100 29 30 4774,77 4673,77 N88,50W 130,25 S 1331.20 W 52~0 29 0 4862,02 4761.02 N87,53W 128.55 S 1380.03 W 5300 29 0 4949.48 4848,48 N85.58W 125,64 S 1428,42 W 1042,66 S 83 26 11 W 1092.26 S 83 31 35 W 1141.66 S 83 36 50 W 1190,66 S 83 42 59 W 1239.36 S 83 54 15 W 1288,28 S 84 9 20 W 1337.56 S 84 24 42 W 1386,01 S 84 40 40 W 1433,94 S 84 58 22 W SECTION DISTANCE 123.61 153.05 185.60 222.65 263,69 ~07,72 ~53-81 ~00.19 446,44 492.96 540,95 590.89 641,57 691.68 741.33 791,07 841,31 891,62 941.59 991.59 1041.20 1090.82 1140.24 1189.29 1238.i2 1287.24 1336,70 1385.33 1433.45 N!ON MON.A-9 RD. GYROSCOPIC SURVEY RECORD OF SURVEY JOB NO 4470 14 MAY 81 TRUE CAS, DRIFT VERTICAL EPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 5400 29 0 5036,94 4935,94 N83'65W 121,10 S 1476.69 W 5500 29 0 5124,40 5023,40 N84,38W 116.04 S i524,91W 5600 28 0 5212,28 5Ill,28 S86,55W 115,14 S 1572.56 W 5700 27 30 5300,78 5199,78 S83,8IW 119,05 S i618,95 W 5800 27 30 5389.48 5288,48 S84.91W ".--1"J23,58 S 1664,91W 5900 27 0 5478,38 5377.38 S84,96W 127.62 $ 1710,51W 6000 27 0 5567,49 5466,49 S85,13W '~1,54 S 1755.74 W 6100 27 0 5656,59 5555,59 S87,16W 134, S 1801.04 W 6200 27 0 5745,69 5644.69 S88,23W 136, S 1846.40 W 6300 27 0 5834,79 5733,79 S88.'40W 137. S 1891,78 W 5400 26 30 5924,09 5823,09 S88~48W 138. 1 5500 26 30 6013,58 5912,58 S89,56W 5600 25 .0 6103,65 6002,65 S89,33W .1.40,14 $700 25. 0 6194,28 6093,28 S89,50W '~'1'40.57 S 2067,09 W 5800 2~ 30 6285,09 6184,09 N86,66W 139,54 210'8'93 'W 5900 25. 0 6375,90 6274.90 N87,38W '.~1~7.36 S 2150.74 W ?000 25 0 6466,54 6365,54 N87,21W 135.37 S 2192,96 W DTTOM HOLE CLOSURE 2197,13 FEET AT S 86 28 2 W CLOSURES DISTANCE ANGLE D M S 1481-65 S 85 1~8 42 W 1529.31 S 85 38 53 W 1'576.77 S 85 48 43 W 1623,33 S 85 47 38 W 1669,49 S 85 45 16 W 1715.27 S 85 43 58 W 1760.67 S 85 42 55 W 1806.06 S 85 43 34 W 1851,43 S 85 46 28 W 1896.79 S 85 50 7 W 1941,75 S 85 53 45 W 86.31 S 85 57 50 W 2029,67 S 86 2 26 W 2071,86 S 86 6 3,4 W 2113.54 S 86 12 51 W 2155.12 S 86 20 43 W 2197.13 S 86 28 2 W DOG LEG SEVERITY DEG/IOOFT 0,937 0,356 2,235 0,768 0,508 0.500 0,076 0-923 0.484 0.076 0,500 0,483 1.501 0-070 0.827 0.516 0-070 SECTION DISTANCE 1481.34 1529,16 1576.67 1623,21 1669.36 1715,13 1760-51 1805.91 1851,30 1896.67 1941,66 1986,23 2029.62 2071,82 2113,52 2155,I2 2197,13 NION MON.A-9 RD. GYROSCOPIC SURVEY JOB NO 44?0 · EASURED DEPTH AND OT~ER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, MAY 81 TRUE MEASURED VERTICAL SUB ND-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 201 301 401 501 ~ 601 701 801 902 1002 1102 1202. 1302- 1402 · 1502 1602 1702 1803 1903 2005 2106 2208 2310 2413 2517 2622 2728 2837 ,. 2947 3060 3173 3286 3400 3514 3631 3747 201. 100 0 0 301. 200 0 0 401. 300 0 0 501. 400 0 0 601, 500 0 0 701. 600 0 0 801. 700 0 0 901. 800 1 1 1001. 90O 1 0 1101, 1000 1 0 1201. 1100 1 0 1301. 1200 1 0 1401. 1300 1 0 1501. 1400 1 0 1601. 1500. 1 0 1701, 1600 I .... 0 1801. 1700 1 ....... 0 1901, 1800 2 1 2001, 1900 4 2 2101. 2000 5 1 2201, 2100 6 1 2301, 2200 9 3 2401, 2300 12 3 2501. 2400 16 4 2601. 2500 21 5 2701. 2600 27 6 2801. 2700 35 8 2901. 2800 46 11 3001. 2900 58 12 3101- 3000' 72 14 3201, 3100 85 ..,. 13 3301, 3200 98 13 3401. 3300 113 15 3501. 3400 130 17 3601, 3500 146 16 0.00 S 0,00 N 0,97 N 3,57 N 6.36 N 10,44 N 16,08 N 22,31N 27,81 N 32,75 N 37.24 N 40.90 N 44,03 N 46,69 N 47.40 N 44.41N 41.46 N 40.19 N 39.06 N 37.61N 35.94 N 33.71N 30.58 N 27.36 N 24.65 N 22.32 N 19.08 N 13.69 N 3.95 N 7,27 S 19.10 S 32.40 S 46,11 S 60.15 S 72.44 S 0,00 W 0.00 W 0.75 W 1.'02 W 1.55 W 1.07 W 1.30 E 4.01E 6,06 E 7,83 E 9,47 E 10.83 E 11.76 E I2.69 E 15,34 E 15.59 E 9.42 E 2.63 W 18,61W 36.16 W 55.29 W 77.07 W 102,18 W 130,34 W 161,75 W 197.16 W 239.19 W 285,32 W 336,00 W 387.88 W 439.62 W 491.70 W 546,02 W 603,87 W 662,03 W ¢ION HO,N.A-9 RD. GYROSCOPIC SURVEY ,JOB NO 4470 · 'ASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 14 MAY 81 3863 3978 4094 4209 4325 4440 4555 467I 4785 4900 5015 5130 5244 5359 5473 5587 5700 .5813 5925 6038 6150 6262 6374 6486 6597 6707 6817 6928 3701, 3600 162 16 3801, 3700 177 15 3901, 3800 192 15 4001, 3900 208 16' 4101, 4000 224 16 4201, 4100 239 15 4301, 4200 254 15 4401, 4300 270 16 4501. 4400 284 _. 14 4601. 4500 299 15 4701. 4600 314 15 4901., 4800 343 ili! 14 5001, 4900 5101. 5000 5201. 5100 5301. 5200 5401. 5300 5501. 5400 5601. 5500 5701, 5600 5801. 5700 5901. 5800 6001, 5900 6101. 6000 6201. 6100 6301. 6200 6401, 6300 358 372 386 399 412 424 437 449 461 473 485 496 506 516 527 83,20 S 92,85 S 101,06 S 107,37 S. 112,70 S 116,92 121,55 S .126,20 S 130,30 S 131,60 S 131,04 S 129.69 S 127.27 S 1 : :ii19.05 s 13 124 · 2 1 5 12 ' 128,78 5 13 132,91 12 135,67 12 137,39 12 138,91 12 140,02 11 140.46 10 140.61 10 139,05 11 136,75 718.98 W 775.86 W 833,50 W 891.19 W 948,94 W 1006,23 W 1062,92 W 1120.23 W 1176.11 W 1232.35 W 1289.08 W 1345.93 W 1401.33 W 1456,84 W 1511.84 W 1566.45 W 1618.95 W 1670,86 W 1721.80 W 1772.76 W 1823,64 W 1874.53 'W 1925.14 W 1975.10 W 2023.55 W 2070,04 W 2115,98 W 2162,42 W NION MON,A-9 RD. NTERPOLATED VALUES FOR EVEN TRUE MEASURED VERTICAL DEPTH DEPTH 1000 999, 2000 1996, 3000 2948, 4000 3819. 5000 4687, 6000 5567. 7000 6466. GYROSCOPIC SURVEY JOB NO 4470 1000 FEET OF MEASURED DEPTH, SUB SEA TOTAL COORDINATES 898. 27-73 N 6.03 E 1895. 38.99 N 17.81W 2847. 9.29 N 308.83 W 3718. 94.59 S 786.72 W 4586. 130.74 $ 1281.58 W 5466. 131-97 S 1755.70 W 6365. 135-15 S 2192.94 W 14 MAY 81 UNION OIL OF CALIFORNIA A- 9 REDRILL GY ROSCOPI .0~ CU~AT~ g MAY VERTICAL PROJECTION UNION OIL OF CALIFORNIA MONOPOD A-9 i REDRILL GYROSCOPIC-SURVEY RADIUS ~OF__ CURVATURE SCALE I I000 · TMD -' 7000' I t~ *,' c ..' , Check !'Oll11 I; I for ti¡oc,lv cŒl!jliance \~ith our regulations. , ~ L ~ . I)YJlðt1 - rß5 1f-rL1L- Op2rc1tor, \';e11 EëlITC <J.nd NWTÙ..X;r Reports and t.iatcria1s to tc received by: &, -It) -9'1 illte ¡ RO::luircd : Dùtc Rcccivcc..l ¡ Rc.:rna.r}:s : I ! - . I I I I I , Ccmpletion Rq:ürt t--____Yes___1 9 -li- 3Ll' L fiT/? . I I I . : 1_.~~!_3_::1r-- gL : ¿~, te- I ¡ ,¡ . , I Samples -L&~-¡¿ll - I ðK, I. I ¡ I I Mud Wg . 1-,&0 I!- I I -- l IJJ:. ¡ I I eoceGlips ' I, '4lJJ.JIîi.l". '---- r- -...i --.-. 0 K I. I I . ) Cqre $scription i i 11./ I ~'I () I< ! IVO¡vb ' ¡. Registered Survcy Plat! /I/t) I ~ ,i ' () I( ! .l... ----:--'------1'- Incli.nation Survey ! ----.-.i---"--=-- ..... ,¡ & K . . ., .1'S . 'I.' ' ',.> .. ,. ~ I L61 Ducctwna. urvey !._-Y-~~_m. :_Jj~-~"_:. ð~.~I-- . ':'..~ I . I Dril~ Stern, Tcst Rcports I' ,AJQJÙ('~---~.._~- -~-_._---Q~ l"~~---" ~- "------- - I Prçduction Test RCfOrts . ". ,e. s I (p - ( q r 9'( I ,. L It r{ - Ycs l ' L.". - 'p 7 -":z~~¡ L__.. 19-./~ e.6 1]-0 7~g~ Lp.-kf'€l Union Oil Company of Californi;,. ,. Mr. Harry Kugter ko C. Wartnen AT Al askau,,n"~u,,u~-J~,,~e~ XT -v.~..Pn"~h 6247 Conservation Co~.. Anchorage, AK 99502 Anchnraoe. AK TELEPHONE NO. TRANSMITTING THE FOLLOWING.: TRADING BAY STATE A-17 RD (~4-4)' '1 ea sepia and 1 ea. blueline of the following' compensated densilog coml)ensated ~eutrun caliper log 2" cOmper~Sated densi log ~.." compensated densilo9 2" BHC acoustilog 5" BHC acoustilog ., 2,' dual laterolog 5, dual laterolog 1 ea. sepia and 1 e~ hl ,~1 i ne of the fo11 owi nq' 5" dual laterolog 2" dual lateroloq _ 5" borehole compensated sonic loc ,. 2" borehole compensated sonic lo~ comp. neutron formation ]ensity /nnmD. formation density loq / . ~ ~F~qF~qTGN_AND RFTi~N ONE ~3PY _ .... .... ~ATF: ,,,, ~as~ gll &-Gas ~.,.,~. ~,m,,,nission -- A~ohnr~ge .,. ./~ STATE OF ALASKA ~-~ MONTHLY ALASKA? ~.AND GAS CONSERVATION ,MISSION REPORT OF DRILLING AND WORKOVER OPERATIO#$ {5 · Drilling well~] Workover operation ~[~ 2. Name of operator UNTON OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99.502 4. Location of Well at surface 1625'N & 566'W f/ SE Corner, Section 4, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 101' RT above MSL ADL 18731 7. Permit No. 67-14 8. APl Number 50- 733-70062 9. Unit or Lease Name Tradinq Bay State 10. Well No. TBS ^-gRD 11. Field and Pool TRADING BAY - HEMLOCK For the Month of JUNE ,19 81 12. Depth at end,of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 7032' TD Commenced operations O0:Ol hrs 6/4/81. Removed tree, installed & tested BOPE. Pulled 2 7/8" tubing string. Cleaned out sand from 6563' to 6894', Reran 2 7/8" completion assembly and released rig @ 24'00 hrs 6/5/81. 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 certify that the foregoing is true and correct to the best of my knowledge. 'o'/~ --I~eport on t~is ;o;~'is req~i-re~ for eaCh calendar m°nthl ~eg-~-rdle-~s ~-f ;h~ st--~-tus of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate . sTATE OF ALASKA ~ ALASKA~'L AND GA;s CONSERVATION CC/~,MISSION MONTHLY REPORT DRI'LLINGAtlB' R OVER OPERATIONS Drilling well 2. Name of operator UNION OIL 3. Address :Workover operation [] PO BOX 4. Location of Well COMPANY OF ~:CALIFORNIA 6247 ANCHORAGE AK 99502 atsurface 1625'N & 566'W from SE Corner, Section 4, T9N, R13W, SM. 6. Lease Designation and Serial No. ADL 18731 5. E;levation in feet (indiCate KB, DF, etc.) 101' RT above MSL 7. Permit No. 67-14 8. APl Number 50- 733-70062 9. Unit or Lease Name TRADING BAY STATE 10. Well No. TBS A-9 RD 11. Field and Pool TRADING BAY - HEMLOCK For the Month of. MAY ,19. 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 7032' TD 6886' ETD (Ret) 13. Casing or liner run and quantities of cement, results ~f pressur9 tests 7" casing f/ surface to 7020' cemented w/ 1000 sXs. Pressure tested to 2500 psi. 14. Coring resume and brief description None. 15. Logs run and depth where run CBL-VDL-GR f/ 6976' ETD to 3500'. 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perforati ons' 6826-6876' 6730-6755' 6663-6693' RE£E VED JUN 1 ~ 1981 .r,,-.,., P,,;n~' Pnrnm|ee|nn 17. I hereby certify that the foregoing is true and correct to the best of mY knowledge, Alaska 0il & .............. , Anchorage SiGNEr~/_/,~..~//~~/j~//~TiTLE DIST DRLG SUPT. DATE6/15/81 NOTE--R~port- r - i - ---- ~o~ this f;rm is re;uired f~rr each calendar month, regar-dless of the status of operations, and must be filed in duplicate with the Alaska. Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate ' ' STATE OF ALASKA ALASKA/'~:L AND GAS CONSERVATION C(~IMISSION MONTHLY REPORT' UF DRILLING AND WOF OVER OPERATIONS 1. Drilling Well ~] ' WorkoVer operation [] ' 2. Name of operator 7'. Perm~'t No. UNION OIL COMPANY OF CALIFORNIA 67-14 3. AddreSs 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 so-733-70062 4. Location of Well at surface 1625'N & 566'W frOm the SE corner, Section 4, T9N, R13W, SM. '5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 10l' RT above MSL ADL ]8731 9. Unit or Lease Name TRADING BAY STATE 10. Well No. TBS A-9 RD 11. Field and Pool TRADING BAY - HEMLOCK For the Month of APRIL ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 7032' TD, washed over and recovered 9 5/8" casing from 465' to 499'. Milled window in 13 3/8" casing from 380' to 460'. Laid KOP. Commenced drilling off KOP @ 385' on 4/12/81. Drilled to 7032' TD. 13. Casing or liner run and quantities of cement, results of pressure tests 9 5/8" casing @ 1995' Cemented with 400 sx c] "G" with 45 pre-h~vdrated gel and 2% CaCL2 followed by 250 sx c] "G" with 2% CaCL2. 14. Coring resume and brief description 15. Logs run and depth where run DLL-SP-GR, FDC-CNL-GR, and BHC-Sonic-GR from 7021' to ]995'. 16. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED MAY 1 ~ 198l Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~-,--\~.kL~-~.~..z~t~--~-~~l,ltE DIST. DRLG, SUPT. DATE 5/12/81 NOTE--Report/on this form is required for each ca~ndar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate l~rch 24, 1981 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Re: Trading .Bay State TBS A-9 RD Union Oil Company of California Permit No. 81-36 Sur. Loc.: 1625'N 566'W fr SE cr Sec 4, T9N, R13W, SM. Bottomhole Loc.= 1530'N 2700'W fr SE cr Sec 4, T9N, R13W, SM. Dear Mr. Anderson: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Hr. Robert~ T. Anderson -2- Tradi~ng- Bay State TBS A-9 RD March 24, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. · TO aid us in scheduling field work, we would appreciate your notifying~ -this office within 48 hours after the well is spudded. We would also like to be notified so that a 'repre- sentative of the comm/ssion may be present to witness testing of blowout preventer e~pment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adepts advance notification so that we may have a Enclosure cc~ ~partment of Fish & Game, Babitat Section w/o encl. Department of Environmental Conservation w/o/encl. ALASKA OIL AND GAS CONSERVATION COMMISSION ,lAY S. HA¥¥OND, ~,OV£RNOR 3001 PORCUPINE DR/VE.ANCHORAGE, ,4L~ASKA 99501 March 23, 1981 A D M I N I S T R A T I V E A P'P R O V A L NO. 93.5 Re: Application of Union Oil Company of California, to redrill, complete, and produce the Trading Bay Unit A-9RD well. Mr. Robert T. Anderson District Land Manager Union Oil Company 'of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on March 23, 1981 and stated 'that the subject well will provide an effective Hemlock withdrawal point in'the II-A fault block. The request was made pursuant to Rule 5 (b) of Conservation Order No. 57. This order was recinded by Conservation Order No. 93 on July 31, 1970. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion of the referenced Well pursuant to Rule 9 of Conservation Order No. 93. Yours very truly, Commi s sione r BY THE ORDER OF THE COMMISSION ~ Union Oil and Gas D.~sion: Western Region Union Oil Company o1' California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union March 17, 1981 Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Pot Anchorage, AK 99501 Dear Mr. Hamilton: Enclosed are the requested maps for wells A-24RD and A-gRD, Monopod Platform. Also enclosed is a revised Permit to Drill and abandonment procedure (Sundry Notice) for A-9RD. The Permit to Drill for A-24RD transmitted December 17, 1980, will remain as is. The filing fees for both these wells were transmitted on December 17 also. Sincerely, Dist. Drlg. Supt. RECEIVED MAR 1 7 1981 Alaska Oil & Gas Cons. Commission Anchorage la. Type of work. STATE OF ALASKA ~ ALASKA ..,IL AND GAS CONSERVATION C~.wlMISSION PERMIT TO DRILL 2O AAC 25.O05 DRILL [] lb. Type of well EXPLORATORY [] REDRILL [~ DEVELOPMENT OIL ~l DEEPEN [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I-1 SINGLE ZONE ]l('l' MULTIPLE ZONE [] 2. Name of operator UNION 0IL COMPANY OF £ALIFORNTA 3. Address PO BOX 6247 ANCHORAGE AK 9950_2 4'L°cati°n°fwellatsurface]625'N & 566'N from SE Corner, Sec. 4, T9N, R13W, SM. At top of proposed produc~ng interva~ 1600'N & 2500'W of SE Corner, Sec. T9N, R13W, SM. At tota~ depth 1530'N & 2700'W of the SE Corner, Sec. 4, T9N, R1 3W_ RM 5. Elevation in feet '(ir~d~t'e K-~,' [:)F etc.) 6. Lease designation and serial no. 1C)l ' Et: above_ MSL ADL-1R731 12. Bond information (see 20 AAC 25.025) 9. Unit or lease name TRADING BAY STATE 10. Well number TBS A-9 RD 11. Field and pool TRADING BAY - HFM/0£K Type Statewide Suretyand/ornumber United ]Pacific Ins. Co. Amount $1OO,OOD.OO 13. Distance and direction from nearest town 14. Distance to nearest property or lease line [ 15. Distance to nearest drilling or completed 27 aired.miles North of miles 4,770, 00 feet ] well 650 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7500' MD 7?00' TVF) feet 4/1181 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures Il00w psig@ Surface KICK OFF POINT ~ feet. MAXIMUM HOLE ANGLE 30 oI (see 20 AAC 25,035 (c) (2) 2000'k* psig@61 00'Sft. mD (TVD) 21 *Assum.ing gas grad.ient tn surface **Der'ired from ex.ist'ing 6201' VD ~roposea t;as~hg, Liner and Cementing ~'rogram rosor¥, ~ ? da_~a_. SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing g l/2 ' 7" Weight Grade ?q~ 47# N-80 N-80 22. Describe proposed program: CoupIing Length R,,~ 6800' I I ?000' MD TOP surfac~ II TVD MD BOTTOM TVD 6800' ~I 64~0' +2000'! +!990' )-- (include stage data) 750 CL!, ft_ 600 cu_ ft. (See attached) RECEIVED MAR 1 ? 1981 Alaska Oil & Gas Cons. Commission Anchorage 23. I hereby certify that the foregoing is true and correct t° the best oi rn, Yl k~owledge S'GNEDCL~i~---~~~O.~_ ~~/' T,TLE District Land Mgr. The space below for Commission use Rob~rt T. ~ndersc~n CONDITIONS OF APPROVAL DATE 3/17/81 Samples required Mud log required []YES ~0 []YES ~0 Permit number Approval date APPROVED BY Directional Survey required 2f-Y ES ~NO IAPI number 5o- 73 3- ~ooo.L-o / SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM I SSl ON ER DATE by order of the Commission Form 10-401 I::~w '7_1 _~ Submit in triplicate PERMIT TO DRILL TRADING BAY STATE A-9 22. Describe proposed program' · 4. 5. 6. 7. 8. 9. Move rig over TBS A-9 and rig up. Kill well, remove tree, install & test BOPE. Pull and lay down existing completion equipment and abandon old hole thru cement retainers (See Sundry Notice abandonment procedure). Mill over, cut & pull 9 5/8" casing 'from +550'. Cut section in 13 3/8" casing from +490' To +_520' & spot K.O. plug. Directionally drill 12 1/4"' hole to +2000'. Run and cement 9 5/8" casing at +200~'. Directionally drill 8 1/2" hole to +6800' MD. TD. Run logs. 10. RUn and cement 7" casing f/ +6800' to surface. 11. Run CBL & Gyro (sqz as'needed-). 12. Fracture stimulate the Hemlock as justified. 13. Complete well w/ single 2 7/8" gas lift completion. 14. Remove BOPE, install & test tree. 15. Place well on production. A-8 liA-16 A-13 © A-9 RD TOP HEML~ · i~£C£11/ED Alaska Oil & Gas 6000 ~D 6200 TYPE LOG A-6 CURRENT PRODUCERS C) PROPOSED REDRILL C) FUTURE WORKOVERS (IDLE) SHUT-IN OR SUSP. TRADING BAY FIELD TOP HEMLOCK FM 0 I000 FEET CHECK . ¢,~ TE VAL V£ · 'MAR 1. ? Alaska 0il. & Gas Cot Anchora ED 98'1 s. Commis ,4/~'GL EO . F/LL UP LI/~ HYDRIL · .o HYdrAULIC OPERA T£D VALVE , · · LO-FOR~UE ': . GATE VALV£ 'REOU/R£D PIPE NOTE ' . ALL CHANGES N~UST HAVE APPROVA~ BY THE DISTRICT DRILLING SUPERINTENDENT : - ~SUXIL i~ CHOKE . ". ":'"'.:' BUBBLE. 'TA/VK . . .. OR /tOHE HADE DEGASSER · · . ~.'.' : . .. L.P. VAL~E 1 e~ L P. VALVES POSIZTVE CHOKE ADdUS~'4BLF 6HQKE o . Union ~,HI o. i _, IlL J -- : ' I e. · · ! I : _ Il I~ L: · ... .,~,~,,,~o,.,,~2~:~0o,~' .:..., · ..:... ..... .. "'c..,To. ra~' Oom.tTii&t/oo' · I~ 0 T E_'. ' ,i- ALL CHANGES hlUST HAVE WRITTEN ~PPROVAL BY'TH[' DISTRICT DRILLING SUPERINTENDENT. H/N/HUH STA/,'D~RO ' ~/tOKE /,!A/,'/FOLD /SSE/,I£LY · 3~o0 ps/ H,,', /9 · · A.'P'D._ H.B I. None DAIr 9-24-7.3__ Union Oil and Gas~%j~vison: Western Region Union Oil Company 'of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager December 19, 1980 Mr. Hoyle Mamilton State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska permits to Drii~ k-9 Rd/ and TBS A-24 Rd., Mono~~{~rm, Trading Bay Field ADL-18731 (8-86'71-5575-601353) Dear Mr. Hamilton: Enclosed for your further handling are three (3) copies each of the above captionedPermits to Drill. Also enclosed are our checks, numbers 19077 and 19078, each in the amount of $100.00 to cover the required filing fees. Upon approval, we would appreciate executed copies for our files. Thank you. Very truly yours, sk Enclosures ALASKA '~ STATE .OF ALASKA ¢'-',. AND GAS CONSERVATION CC--'MISSION I ERMIT TO DRILL · 20 AAC 25.005 ~-=_~ la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRA~',~RAPHIC r-] ':.- REDRILL E~ DEVELOPMENT OIL [] SINGLE ZONE w---I DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] UNION OIL COMPANY OF CALIFORNIA' -' ,:' ?- P.O. BOX 6247, ANCHORAGE, ALASKA 99502 :·~ ~:.~ 4. Location of well at surface 1625'N & 566'W from S.E. Cor., Sec. 4, T9N, 9. Uni.t,.~'r lease name ~ Ri3w, S.M. TRADING BAY S--~ATE 1_O. Well number At top of proposed producing interval 1600'N & 2500'W of the S. E· Cot. , ~,-,~ Sec. 4~ TgN~ R13~, S.M. -.;' TBS A-9 RD At total depth & 2700'~ of the S.E. Cor.,. Sec. 4, TgN,-- 1530'N 11. Field and pool 5. Elevatio. i.'feet (i.dicate KB, DF etc.) I 6. Lease desig.atio, a,d serial .o. /' TRADING BAY - HEMLOCK ., , 101' Rt. abqye MSLI ADL-18731 ,' 12. Bo.d information (see 20 AAC 25.025) '~ Type Statewide , Surety a"d/°r "umber United Pacific;~Ins. Co. Amou.t $100,000.00 · '13~.JDistance and direction from nearest town · 14. Distance to nearest property'S lease line 15. Distance to nearest drilling or completed 27 air miles North oI ., · .... ;~ . . ,, . m,,es ' 3,750.00 ./ tee, well 650 feet '16. Proposed ~~D & TVD} ' 17. Number of acres in le'as%j¢ 18. Approximate spud date 7500' ~9 7200 ~V9 ~eet 3 840 ~ Ac ~/~5/8~ 19. If deviated (see 20 AAC 25.050) KICK OFF pOiNT 265 feet. MAXIMUM HOLE ANGLE 30 I (¢~ 20 AAC 25.035 (c) (2) 2000~*. psig~61 O~ ~ ~ TD (TVD) 21 *ASSUD~Qg gas g~ad~e~t to su~ace/~ **De~ved ~om ez~st~g 620Z'V.D. . Proposed Casing, L~r and Cementing Program sIZE CASING AND LINER ~"' ' SETTING DEPTH ~ese~o ~QUANTiTY~t8OF CEMENT' ' Hole Casing Weight Grade Coupling Length ~ ~ MD TOP TVD MD BOTTOM TVD (include stage data) 8~" 7" 29# N-80 3att 680~4' su~a~e 6800' ~,6450' 750 ~.. I ;~ I I ~- ~ ,, 22. Describe proposed program: ~ ~. Move rig over TBS A-9 and rig up. 2. Kill well, remove tre~''' install & test BOPE. · 3. Pull and lay do~ exi~ting completion equipment and abandon old hole thru cmt. ' ret. set ~ + 1100'..~" 4. Mill over,.c~t &'pull 9 5/8" casing from + 340'. 5. Cut section in 13 ~ " -- .<3/8 casing from + 260' to + 320' & spot K.O. plug. 6. Directionally dr~ll 12~" hole to + ~500'. -- 7. Run and 'cement 9#~5/8'' csg. ~ + 1~0'. 8. Directionally ~ill 8~" hole t~'+ 6800' ~'. TD./'f3' Complete well 'W/single 2 7/8 9. Run logs. ? -- 10. Run & cement /~" casing f/+ 6800' to surface / gas lift completion· 11. ~un ~BL & py~ .(sgM. a~needed). ' /14. Remove BOPE, install & test Tree. I 12. ~'raccure sn~mulate ~he Hemlock as justified /]5. P~ce well on ~ 23,1hereby certify that the foreg~ing is true and correct to the best~f~ ~edge ~ sIGNED~~//~ The spa~below for ~omm~sion use ~-~ 'ITEL ~S~C~ ~a~..~ . DATE / CONDITIONS OF APPROVAL Samples required Mu'd log required Directional Survey required ! APl number ~YES ~ ~NO ~YES ~NO ~YES ~NOI 50- ~Permit 'number Approval date ' SEE COVER LETTER FOR OTHER REQUIREMENTS .......... I , , , , , ~ , APPROVED BY ,COMMISSl ONER DATE .. by order of the Commission :orm 10~,01 ~ev, 7-1-80 Submit in triplicate CURRENT ~RODUCERS PROPOSED REDRILL FUTURE WOHKOVEfl$ (IDLE) SHUT-IN OR SUSP. A-8 I~A-16 A-13 0 .~RD 0 MONOPOD - _ · - . - TYPE LOG A-6 6000 'TOP HEMLOCK 6200' TOP WEST FORELAND-- - 0 I000 FEET " *TANK * ' *' ' -'*. ":'":*.' BUBBLE' · -. * .. OP~ ttO~-:t£ /dADE DEaASSE£ . '.. · .- :~ i'. ' -": :: - . - . .., .>-.-.., .-: ~ . - ' L.-'-- ~-- o - , ;' "'---'""-- - -" - :: ~'-'-- 4" .- .-' '-. 'ii'--. ~':.:"' .- .:. *. . . -.;-: ... ~'... - . . :.' ;;~. ~- -. . ~ . . o ~ ~--"'~ ~'.- ... >....' ...... . o · · ...:..':~.:._~'..:'~~. oo o o - . GAUGE . . · Un/on ~r;ll fu~n/$h l_ P. VALVES POSITIVE CHOKE- · . o. I41NII,!U/,! ST4I;OARO C'ttOKE I,!A///FOLD ASSEIf£LY ADJUS'~-4eL£ . ~HOKE. 3oO O " ? s /' H,/, SCAtl None £HECK V~LYE ~ATE ~ · o ,~t(GLED .FILL UP LllI~ o o , HYB ~A ~IL I£ OPEP~4 TED VALVE· . . · o · , , , .~L.~.~7.:.o-. ..-..t,-,..., .. ~,. STATE OF ALASKA /'~ ALASKA iL AN D GAS CONSERVATION C 1MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] · COMPLETED WELL:~ OTHER [] , 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA 7. Permit No. 67-14 3. Address 8. APl Number P,O, BO× 6247, ALx1CHOt~GE, ALAS~C~ 99502 ~ 5o- 733-7~ I lO. Wt~umber ~¢~1". Field and ~ '[ TRADIN( / Re~p-°rt, or Other Data 4. Location of'Well 1625'N & 566'W from S.E. cor., Sec. 4, TgN, R13W, S.M. BAY STATE 5. Elevation in feet (indicate KB, DF, etc.) 101' Rt. above MSL 12. Perforate Stimulate Repair Well I6. Lease Designation and Serial No. ADL-18731 Check Appropriate Box To Indicate Nature of Notice, NOTICE OF INTENTION TO' (Submit in Triplicate) [] Alter Casing [] · Perfgf~tions [] Abandon I~. sti~ulation TRADING BAY - HEMLOCK SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other D [] [] [] Change Plans [] ?epairs Made Pull Tubing [] Other - . [] ,,/' Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 1074707 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinen~t~details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to abandon the existing/~ellbore in order to redrill TBS A-9, Monopod Platform, as follows: 1. Move rig over A-gRD and rig 9p. 2. Kill well, install BPV, remo~e tree, install and test' BOPE. 3. Pull and lay down existing/completion equipment. 4. Abandon existing' wellbor~¢~ thru cmt. ret. set at +_ 1150' with _+ 300 SXSo cmt. and dump 50 L.F. cmt. O~ top of ret. .: // / / ? ~ .. . . .. . / - -! ::.. :.. ...... 14. I hereby certify ti~t the foregoing is true and correct to the best of my knowledge. The tiP/ace belo~N, ~rC ;mmi ss ion use C/~ditions of Approval, if a;ly: / Date 12/17/80 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 ,~IL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA 3. Address P.O. BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of Well 1625'N & 566'W from S.E. COMPLETED WE LL:J~] cur., Sec. 4, T9N, R13W, S.M. //OTHER I 8. APIJ~lumber _ I o/ 33-700. 2 . Unit or Lease Name TRADING BAY STATE 10. Well Number TBS A-9 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 101' Rt. above MSL 12. Check Appropriate Box To Indicate Nature NOTICE OF INTENTION TO: I 6. Lease Designation and Serial Nc I ADL-18731 (Submit in Triplicate) Perforate [] Alter Casing [] Stimulate [] Abandon [] Repair Well [] Change Plans [] Pull Tubing [] Other [] (Note: Report multiple completions on Form 10-407 with a submit 13. Describe Proposed or Completed Operations (Clearly proposed work, for Abandonment see 20 AAC 25.105-1 TRADING BAY - HEMLOCK' Report, or Other Data SUBSEQUENT REPORT OF: (Submit in Duplicate) Perforations [] Altering Casing Stimulation [] Abandonment Repairs Made [] Other Pulling Tubing [] Form 10-407 for each completion.) [] [] II pertinent details and give pertinent dates, including estimated date of starting any It is proposed to abandon the Monopod Platform, as follows: wellbore in order to redrill TBS A-9, . Move rig over A-9RD rig up. Kill well, install B remove tree, install and test'BOPE. Pull and lay down [sting.completion equipment. ~) Abandon existing thru cmt. r~t. set at ~ 1150' withes_ 300 sxs. cmt. and dump 50 L.F. cmt. on top of ret. ~-~ '~ 14.1 that the foregoing is true and correct to the best of my knowledge. Dist. Drlg. Supt. Tit~e Commission use tions of Approval, if any: Date 12/17/80 ~ By Order of Approved by ? COMMISSIONER the Commission Form 10-403 Date Submit "'Intentions" in Triplicate and "Subsequent Reports" in Duplicate Rev. 7-1-80 ~ STATE OF ALASKA ALASKA L,,L AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGR,~"HI0r~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator UNION OIL COMP~ OF CALIFO~IA / 3. Address ~' P.O BOX 6247, ~CHO~GE, ALAS~ 99502 / ' 4. Location of well at surface 1625'N & 566'W from S.E. Cur. , Sec. 4, T9N 9' Unit °rJ~ase name T~ING BAY STATE Ri3W, S.M. 10. ~11 number At top of proposed producing interval 1600'N & 2500'W of the S.E. Cur., Sec. 4, T9N, R13W, S.M. /'TBS A-9 RD At total depth 1530'N & 2700'W of the S.E. Cur., Sec. 4, T9N, ~'l. Field and pool R13W~ S.M. 5. Elevation in feet (indicate KB, DF etc.) ~ 6. Lease designation and serial no. ~? T~DING BAY - HEMLOCK I 101' Rt. above MSL ADL-18731 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number United Pacific ,~s. Co. Amount $100,000.00 . l~istance and direction from nearest town 14. Distance to nearest property ~ease line 15. Distance to nearest drilling or completed / air miles North of miles 3'750.00 ,/'? feet well 650 feet 16. Proposed ~~ D & TVD) 17. Number of acres in lease,?' 18. Approximate spud date 7500' ~ 7200 TVD feet 3,840.~'' Ac. 1/15/81 19. If deviated (see 20 AAC 25.050) ~ 20.~nticipated pressures 1700' psig~ Surface 21 ~As sg~;let ga; xist 'V.D. reservoir data. SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Lengt~~ MD TOP TVD MD BOTTOM TVD (include stage data) 8~" 7" 29# N-80 Butt 68~' surface 6800' ~6450' 7.5~ ~,.,-. 12~" ) 5/8" 47# N-80 Butt ~00' " ~ ' --- ~ ]500' 11400' ~50 cu. ft. // 22. Describe proposed program: / ~ ~ 1. Move rig over TBS A,y and rig up. ~k ~'L 0 2. Kill well, remove-~ge, install & test B~. 3. Pull and lay do~.~xisting completion e~mentWand abandon old hole thru cst. ret. set ~ + 110~. ~' ' 4. Mill over, ~ut ~"pull 9 5~" casing~{r~ + 340'~ 5. Cut section in;~3 3/8" c~g from ~60'~o + 32-0' & spot K.O. plug. 6. Directionally/drill 12~h~e to +~5~0'. -- 7. Run and cem~ 9 5/8" ~~+ ~~. ~~~e~~~~~~~ ~' - r~ i~~"~~~~~~~~~ 8 ~ f ~e'TD ~~~ ~~~~~~~~ ...... 0~~~ ~~~ ~~~ 1 ~' 2t '7s/t'e 8" 12: Fractu~ stmmuia~ Hem~ a~'justified. /]5 p~ ~7~11 mn 23. I hereby certify that ' oregoing Ls t~ and~Sect ~est~ ~qo~edge ~ TE The ~~r'~si~ use'~ ) ~V ~ ' R~ert T. A zae~ V/ / -- CONDITIONS OF APPROVAL / '" ~YES /~O ~ ~ES ~NO MYES ~NO 150-- ?J~- Permit umber ~pproval date ~ ' ~O (~ ,./ SEE COVER LETTER FOR OTHER REQUIREMENTS I APPROVED BY ~ ,COMMISSIONER DATE by order of the Commission Form 10401 Submit in triplicate Rev. 7-1-80 CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE (1) Fee ~~. .~-/?--~;~.~ 1. (2) Loc. ~d/<~ ,,Y-ZD-// '~"? 2. , (2 thru8) ~ 3. 5. 6. 7. 8. (3) Admin .~< ..~-2J.-3¢/ ~,i~~ 9. (9 thru 11) ' 10. 11. (4) Cas9 ~ 3~/~,, ~ (12 thru 20)' ~<~' 12. 13. 14. 15. 16. 17. 18. 19. 20. Is the permit fee attached .......................................... YES NO Is well to be located in a defined pool ............................. ~ Is well located proper distance frcra property line . ,.. .............. Is ¢~11 located proper distance from other %ells .................... Is sufficient undedicated acreage available in this pool ............ ~ Is %~11 to be deviated and is well bore plat included ............... Is operator the only affected party ................................. ~' Can permit be approved before ten-day ~ait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... ///c~o/~u/c t o?r~ Os~tr'~n?pr ovi de d... ' ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings '''-~ Will cement cox~r all known productive horizons .... ~¢ill surface casing protect fresh ~ater zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore akandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... (21 thru 24') ..~' 21. 22. 23. 24. Is a diverter system required ....................................... .. cq-~ Are necessary diagrams of diverter and BOP equipment attached ....... ~_ Does BOPE have sufficient pressure rating - Test to 7 ooo psig .. r~_ Does the ohoke mnifold comply w/API RP-53 (Feb. 78) .................. - jP~ ~/~-~~g~ (6) Add: 25. Additional requirements ............................................. Additional Remarks: Geology: Engin~e. rin9: JKT --~ RAD ~ rev: 03/10/81 INITIAL : GEO. UNIT !ON/OFF POOL CLa~S STATUS AREA NO. SHORE _ CHECK LIST FOR NEW WELL PERMITS Company ~:~,~"~'~.. Item Approve Date Ye s ('1) Fee /~,~. ;~-~-~ 1. Is the permit fee attached .......................................... ,~ ~ /- 2. Is well to be located in a defined pool ............................. :~ , (2) Loc. (3) ktmin. No 3. Is a registered survey plat attached ................................ / 4. IS well located proper distance frcm property line .................. 5 Is well located proper distance frcm other wells ........... · ........ · 6. Is sufficient undedicated acreage available in this pool ......... 7. Is wel 1 to be deviated ............................................. ~,'~ ...... 8. Is operator the only affected party ................................. 9 Can permit be approved before ten-day wait ........... q~. ... - / 10. Does operator have a bond in force .................................. 11. Is a conservation Order needed ................... 12. Is admin±strative approval needed ................................... Lease & Well No. /~ ~Q, Remarks 13. Is conductor string provided .......................... used to circulate on conductor and surface ......... ~ 14. Is enough cement (4) Casg~ /~,~3-/O 15. Will c~ment tie in surface and intermediate or production strings ...~_ · . 16. Will cement cover all known productive horizons .................... ~ 17. Will surface casing protect fresh water zones ...................... ~~ · ' 18. Will all casing give adequate safety in collapse, tension and burst.~ ~ (5)BOPE ~ /~//_~ 19 Does BOPE have sufficient pressure rating - Test to ~dD~x~ psig . Approval ReccmmP_nded: Additional Requirements: Geology: Engineering: rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding, information, information of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. ' ' ~. . _. ~From the Desk R. C. WARTHEN ANCHORAGE, ALASKA · *~ Ii,;ft.l.,:<.~-:L'll{JN HkCORD,5 ** CN ~: i..l k,' i t.) I,~ [.I ]. I. 'wN : 'L'ig 5 [~L;.33 X Y f'N : ;'IF!Al)Il,'(; I:. i ~' RANG: I ~v.~ 'I'Lt~' i'i: SI.CI': SI:AT: C'J l-', ¥: ** PECO~.;b q, ii'k 047 ~ O0 C, 0(,.0 000 () () 0 0 o 0 OOC, OCC, O00 000 '1' ¥ I:: ~', 000 0 u 0 000 0 O0 000 O00 (]( 0 f) 0 U 00 0 (:ATE noo SIZE. 010 010 015 O0 3 002 001. 0(.)5 O) 0 t) 05 008 CODE Oe)5 065 065 Oe~5 065 065 O65 ('Olde 065 . 3001 Porcupine Driv~ · Ancharage~ ~ ~ Gas Cons. Commissioa Anchorag~ / 81~[ e"l12" / tLlliL; Ri.F .619 (,~ 64 :i_[~ S~ mD$'i'ON~ P~ a'i P, 1 :X .......... CuED q 1 $ 9 4 DLp~i' G? L,L i, bLS bbb Htit]6 t NP~J r DI~IiIJ Fi)fi NChL r ~.C ['; b .V "i F ,1 C A T I.[,' x,i 15 L O C I', S ["1" GA[,.:] ,q V tJ h l~', b, GA[:.']. G/C3 i~, lJ GIC 3 U u.b"I L, LU CAbl i~ t~ A T CAL, I -999. 1 u 0 U 790 8.100 2,~82 [,~ C t',~ L, AP1 APl LOG ~] Y'PI~' 0 ,0 0 31 0 1 0 0 0 0 60 31 60 52 42 31 ;42 2d 42 35 42 0.~ 4.2 4q 42 42 42 "3q '42 3~ -999,250 -999,250 4. 55.30o -0.3 38 ~.. j 33 '0 52 0 0 0 32 32 1 2 0 1 $2. 5GF', / DEr,~ 73 / VI,SC 43 / PH 9.5 -/3 65 E N'I' [~ '6 .lin fL:!' [. F C i~ L · -9q9.250 bLS -9q9.250 -3.059 .ge, 9. 250 L].,S 66.9(,)0 1.11 .628 REPR CODE 68 b8 6~ 68 68 68 68 68 68 58 68 68 -999,250 0 o 000 0. 000 11 .803 5. 700 0.001 '( bt,D -999 . 250 G~ Cat, 1 t~. 1 (tO I~H.O b a b ~ 'I' 4. ~ ~ ~ N.C ~,~h DL P'.[ 294. 000 Gl< LLD -999. 250 GH CAb[ ~.200 HH(Jb Nt~ A'I-' 0.624 t~C c~l, -999.25(~ gl' -999.25(; Dq' 153.'~(;5 [CNI., -999.250 -999.2%O 14.584 -qqq.25U -999,250 2.453 -99~.250 -999.250 -3.0~0 -2~.080 G P I) b H fi.' DL~O PAGE -999.250 2B .000 -0,272 -999.250 0,000 0.000 RE'CEIVEI) MAYO ~ 1.982 Alaska:Oil& &as Cons. ~mmL~s/on Anchorage PAGE */ ** FIhE HEAORR ** FILE nAr'~: :SER~.LO.O( ] SgRVl3~ ~A~'~i VERS I. bi'4 ~ ; D ATE : MAXlaubi LLNG'I'H : 1024 FiLE T 'Y P ~, : PREVIOUS ~" l b~ : ~ECO~DS ~ CN ,: UI,~IUN Oll. WN : 'rF~s [qG.33X ¥ FN : .;'1RADING kal RANG: I ~w TLt~ N: 9i~ SECT; 4 COO~: ~ENAi ~TA~: AbA~Kh C~H~: b~A PRFi$: L'!bbOOl F RECORD T~/PL 047 ** ~IYPE 000 000 000 000 0£0 000 000 T Y 000 CATE OoO 000 000 000 000 000 0( 0 0 O0 000 (,:ATE o00 SIZE 010 010 015 OO3 002 001 OO5 010 O05 SIZE OO8 CODE 065 Ob5 065 065 065 065 065 065 065 CODE 065 ' DA'£~ 4--.2.9-81 ~1) CSG '-y-flu" L.~ 1991' / 811 ~-1/2" / ~'LU]b SGM i DEN ~3 t VISC *.~ RECOHD ]'~Pf 047 ,~ 43 / PH 9.5 ~ b hTU~q ~P~; J~ F,ICAT I.CN MmEM St~Vl£,: DfRVlCf. O~l AP1 APl ~P] ~IPl :FILE SIZE 1D O~)lB ~ LOG ]YPE: CLA~S ~U[) ~0. 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O 00 G R i. 305 G~ 9.500 RH[:~ c~00.O00 GB. 27.797 GR 9.300 R ~i [: ~ 2.q ]2 NCNb b?O0.O('tO OR 6.66t~ GR 2,02~ NCi,tL OhO0. 000 GR 2.642 NCNL {~500,000 GR 8.800 2.570 6400.000 G2 10,864 GR 8.700 RHUB 2.432 NCNL 0300,000' GR ~3.7o0 RHOB, 2.418 NCNL b200.000 GR 8.700 AdOB 2.314 NCNL oIO0.O00 .GR 11.803 GR 9.~00 RHOB 2.184 NCi~L b000.000 G~ 16.596 GR 11.500 3.2.{0 aCi~L 5900.000 GA 13.183 GR 8.500 R~Of 2.402 NC[~L 52.30~) 41 .goo L'] 5~5.bzl ,1~ C ill 54.500 bP 44.30(, 2. 472 NPBI 439.5~. 0 :1' L ~'~L 50. ~,9. OuO gT 2. 372 ~qPhi 492. ti 9.7 0 o $ ~, 42.100 DT 2.428 NJ?hi 433. I B3 ~(jNL 65.400 .5 b. I 00 I;) 2" 2 302 NPH'I 41 C, [ 97'1. 57. ]. O0 60. 800 g I ~ ) 0 . 62.2C ':5 8.500. 2.290NPhl 434.464 FCNL 52.400 ,SP 432..$2M ~ "F. CNL 51.50'0' 48. 500 gq." 2.361'.:: '. N PB 44~.288 ,FCbb 57.603 8P 56;500 2.586 2~3.180 -47;250 LbS ,~9.700 ~F ~',690 Di~EO 258,223 -49.250 LLS (3,650 GR 13.616 DRHO 160.053 -52,000 LLS ~5.40U fir 23,381 DHHO 22S.286 -48,000 bls 77,300 GR 15.447 DRhO 137,~1 -53,750 LLS 93,350 GR 27,631 DRHO 127.910 -43,000 LL8 '~5 ?5 fir 156,531 - 34~ 250 9h. 550 GF 1, -41.000 LI,S 86 ~50 GF. 23[ 94 l)RhO :159.513 -25;50(~ L£,S .59,30 C.I~. -23.500 LI,S . 245 DF. HO 60, 122 -32.750 LLS ~5,2506P ..Zl,:l Dh~O i57',85 q5.290 50.000 0. 025 35,318 49,800 0.017 8.472 51.400 -0.005 7,993 46,600 7.178 60.200 -0.001 11 .912 12.823 58.900 -0.005 11.272 49.8C0 0.001 1 588 0,007 15.70t 61.900 0.093 14.322 47,300 0.019 O, O O Dt;k 'i ~800. uoO bLD ! ! .q~2 GR CALl 9.t~(O i~RA'r 2 · ~q2 .NCNb LLD ?. 727 GR CAbi 8.500 [{HUb NRAT 2.530 NCi~t., DEPT 5b£ O. 0( 0 LLD 54 . .450 CAbI 8.7( 0 NBA3 4.792 NCt';L DEl-T 5500.0Ou (JR LbO 28.8g0 GR CAbl 9.U(0 NI{AT Z .53b NC~NL D,%P? 5~00. 000 Gt{ LLU 9.550 GR CAL[ 1~. 300 Rr~(]6 NMAT 2. 792 NCt,{L OEPT .5 300. 000 l,NO 7.79u CALl 13.900 DEP'i 5200.0(0 GR bLD 73.79 u GB CALl [5.700 EHOB Ni{AT 3.058 iq C ~L DEPT ,klO0.O00 GR bLD 8.017 GR CaLl 15. 300 {~ ~A'I' 3.232 NCi'~ b D~P'£ 5000.000 GB LbO 10.7t5 GR CA~I 10.400 HHUB N~AT 2.9~2 NCNL DEPT 4900 . 000 GM LL, D 46.559 GR CfiLJ 7. 800 N~AT 3.5 I 5 NCI~L DEP~I' q~(] O. 0( 0 GE LbO 7.311 GR CALl 23.3( 0 Ri40~ NF{AT 3. ] ~8 l'-~C NL is'ri NG 40~'.42q f C{';L, 79.000 79.5OO 2.2~ 1 NPh 39b.59~ fCNL 62.500 5 6.300 2.536 225.].65 53. 500 DT 2.2s7 NPhI 399.4.39 FCNL 97.4oo SP 93.50({ DT 37t). 9o0 PCNL 106.3C0 SP 105.000 DT 2.406 NPN1 20~.562 ['CN£, ~. 7, 3CO SP 93;300 I:)T 2.3~5 l',~P H 1 75.5 (:, 7 ~ C N L 91.700 SP u3.5OO bT 2.3fSSP}{i 291.79) FC~L 40.9C0 SP 47. {00 07' 2.3E 3 231.999 95.~O0 SP 9~.900 2.442 ~bhI 305.467 PCND -27.O00 I, LS 8~. 150 Gb 31 .293 D btii [) 10q.144 3. 750 LLS 99. 950 Gi{ 134.520 -2a.ooo I, LS {,2.350 GR 16.798 DR}JO 22.703 -22.500 Li~S 96.850 GR 2~.040 DRH(] 131.438 -24.2750 LLS B 9. 50 GR '.~ ~:81~ 7 D }-~.I~, O I 1 329 - 30,7:5 0 LLS 8 5. 't50 61{ ',2 ~. 6] 7 CRHO 22,703 .1' 0 O0 :>i hi,,% 9.750 GR ¢4,72_ ,9 90.49 ~ -23.250 91.350 GR .41.4~0 DRHO 5'1,921 -24 ~) LLS 1~ 0.gz O1.50~ -2 3.0(0 bLS 8 ,~'. 700 G~ ,19.'l~ 4 DRHO 31.07 I -16 250 LLS q 0: 750 G ~ :3 4, R h [] ~")i 1TM PAGE ~.872 87.800 0.029 0.427 79.000 0.101 36.983 63.700 0.016 24.889 56. 500 0. 003 7.516 96.600 0.106 5.970 98.600 0.059 54.954 55.700 0.045 6,3f8 99.300 0.048 7.727 88.100 .35.845 45.800 O.OOl 6.194 95.700 0.044 I I I I I I I I Ot I I I LLD 21.478 GR N~T 2.152 NC~L OkPT 4500. 000 GR bLP 31 .~23 GR CA61 I '~ .600 R ti(J 6 NRA]' 2.528 NCNL DEP'I' 4500. u00 GR LEO 5.2 ( 0 GM CAbl 15.800 Rt~Ue N HA'I' 3 , 562 NCNL D~PT 4400.000 G~ bbD 3.945 GR CALl 1].100 RHOb NRAT 3.612 NCnb DEBT ~300.000 GH LED 3.981 GM CAhI 8.200 NRAT 2.772 DEP'I 4200.000 GH LLD 4.446 GR CALl 14.400 RHU~ hgA~ 4.370 NC~L DEBT 4100.000 GR l O0 RHO6 NRAT 3.024 NCNb D~PT 4000.000 GR bbD i7.7(1 GR CALl 9.JO0 RHO~ NRAT 2.826 NOel DEBT 3900.'000 GR bbD 4.529 GR CAL.I 8.200 RHG8 NRAT 2.87h ,~O~L DEPT 3800.000 GR LbO 4.529 GR CALl 15.400 RHO~ NRAT 3.954 NCNL DEBT 3100.000 GR bL£) 4.q87 GR CALl 19.200 RH'Ob I~RA'~ ~. 452 NCnL LISTING 43.30) SP 4t).OoO LT 2.405 ~PHI 442.580 -32.300 bls E~.550 'fir 15.491 DHHO J66.216 72.60) bi:, 7'). 6£ 0 BT 1. 794 -25. 250 LES It 1 9. B.~ 0 GR 64. 904 DRMO 157.41] 84.9OO 94. I OD 2.368 234.135 ~CHL -26.750 bls 9o.300 GS 39.554 DRHO 39.431 91. I 00 5 P 90. 200 ET 2.351 ~,.~PH i 260. O i 7 :~ CNL -2~;750 LbS 107.050 fib 47.336 DRHO 49.116 44.90O SP 42 . 400 D 7 2. 336 · t'~PH1 413.534: i;ChL '5' 250 LbS ;::..,. ! 5e 9a.~oo G~ 25 757 DRHO 129:237 101.900 6P '100.500 ~T 2.51) hPHI 219'185 ~CbL -37:.750 LbS ' '.c2' 150 GR.: ::'.;. '; ,~ .~ 35. 979 2 !..823 52-309 SP 52.600 ET 103.250 GR c ' · \ 2.27~ .hPkl..~,~ 33,:5b0 :. DRH[) 329,~!4 ;PC~.~L ~;253 40. 000 5P -31..000 LI~,S 40-400 DT~ . :"' 6 : 76 DRRCt 2.607 [,i PHl 351,599 BCNL'.. 9:2,,699 48.o0·o ss -4~ 500 LbS 47.200 i:T :c, 2:150· GR 3 i' .07:1 l~'Ct~l.., 105.025 ~5.90{') SP - 15. 250 IJI,8 92,000 ET 102 6m50 Gl{ 2.32:,) NPi. il 46:,,,28 DRnO 256'773 :',~CNL 3~'-149 88,303 77.60o [T :Se:050 ~': 28].120'2'351 .FCNL, '57:~.3581 DRBO PAGE 19.231 41.000 0.065 35.975' E2.1. O0 0.019 3.802 93.400 0.046 3.105 1~8.700 0.064 4.406 44.500 0.010 3.802 ISl.700 0.080 · 831 s : oo 0.0O5 18.880 39.300 -0.012 4.61,3 46.200 -0,004 3.251 IE5.700 0.047 3. 342 'E 7.000 0.031 I I I I D V Eli 1F' lC Al'lDr~ L 16~"] I~G PAGE DE.F T bLD CoLI LLD CALl Lbt.) 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'.:i.: '':,""48,000 LbS 5.395 6.730 Gt~ 74.00o DT :113. '500 GR 84.500 21.~(0 R~O~ 2.040 NP~I 56.490 DR~O 0.008 4.b64 NCNB 196.119 PCNL 15.219 D~:PT 2900.000 GR 85.700 SP -43.750 LbS 5.546 hbo 7.2~4 GR 86.800 D~ 88.500 (;~ 90.200 CALl 28 100 RHU~ 1.94e~ b~PHl 57.536 DEMO 0.003 NHAT 4:322 NCNb 229.B63 ~C~L 30.187 D~PT 2SCO.O(0 G~ 92.600 ~P -41.750 LbS 5.861 bLO 8.017 GR 80.500 D'I1 112.650 GR 88.000 D'I 1 j 2,900 GR" 9 00 CAbi 26 CO MaOB J 99 hPH] 53.351 DRHe 0:~34 NEAT 3',314 NCNL 299.915 b"CNL 81:.253 DLPT 2600',000 GR 6~,900.:.8P ,-37 000 LLS 7.112 CALl .000 RHUb 2..~E7 NPhl '~9.0~6 i]RHO 0.062 NEAT 3.622 NCNb 226,01 9 FC J,~ b 35.'029 L LL, D CaL, I bHAT O b, P 1' bL D C^I~I LLD CaLl NRAT L, b D C A L .I DEP'J LbO NRAT DEPT bhO CALl NRAT D5PT CALl N~AT DEPT LLD CALl bRAT DPJPT L L D CALl NRh'I' DkPT bLD CALl hLD CALl NI-<AT 009.ii02 YERIFiCi{T.iL]I~ L, iSTIN't° P~GE 2b00.000 GR 46.100 i 7.06. 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OB 2.225 NPHI ~4.1~9 DRHO -0.35 3 NRAT 5.0~ NCNb 14~.57] f'CNb 4,2 ~ DEP'.[ bO0.0(.)0 G~ -9~ 9.250 SP -99g.250 bLS -999.2E0 ~tjj . . s ' 999.250 DI~P'i' q(u.0(0 GR -999 250 bbt) -:~99.250 GR -~99.253 D'J' 999.250 ' NRAT 5.51~ NCNL 143,581 -999. 250 24. 300 L~/P 009.it02 VE~1rI;IC.ATION LI$~ING I)EP 1'' 390.000 GR I,Ll) -999. 250 GB CAbl i~.100 RliOb NBAT 4.884 NCNL DEPT 294.000 GR bbD -999.250 GR CAb[ U.200 HHOB NRAT 0,624 fiCNi, -999.25O - 999.25O 2,925 153.~()5 -999.250 -999.250 2.503 1~.B84 FiLE N A[,,E :51~,RV iC. 0Ul VERSIon ~ : [)~T~ : MA~IaOlq LEi,~GT~ : 1024 FILE 'I' ~- P ~: : NEXT ~lb~ [~A~.E, : £P DT ?'CNL -9q9.250 -999.250 2.453 -99~.250 -9S9.250 -3.080 -23.080 LLS GP. I) F i-1 LLS DRhO PAGE -999.250 23.000 -0.272 -~99.250 0.000 0.000 4 ,L