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Home My WebLink About166-049CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: Withdraw Sundry # 324-563 - Trading Bay St A-02 PTD: 166-049 Date:Monday, September 29, 2025 1:20:51 PM Hi James, This sundry has been withdrawn in the Wells folder. please do so in RBDMS. Thanks, Grace Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 From: Juanita Lovett <jlovett@hilcorp.com> Sent: Monday, September 29, 2025 11:39 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Eric Dickerman <Eric.Dickerman@hilcorp.com> Subject: Withdraw Sundry # 324-563 - Trading Bay St A-02 PTD: 166-049 Mel, Please withdraw the above-mentioned sundry. Scope of work was to install a subsurface controlled SSSV. Regards, Juanita L Lovett Sr. Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 | Anchorage | AK | 99503 (907) 777-8332 | jlovett@hilcorp.com RBDMS JSB 100325 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install SSC-SSSV 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: Mid Kenai C, 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,669'N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 2,570psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 907-777-8503 Dan Marlowe, Operations Manager 907-283-1329 Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Ryan Rupert, Operations Engineer ryan.rupert@hilcorp.com Authorized Name and Digital Signature with Date: Tubing Size: Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 TVD Burst 3,950psi AOGCC USE ONLY 9.2# / L-80 5,297' Tubing Grade:Tubing MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018731 166-049 Trading Bay St A-02CO 93B SameTrading Bay Field 1,023' Length 50-733-10056-00-00 Hilcorp Alaska, LLC 1,023' MD PRESENT WELL CONDITION SUMMARY Size 6,546' See Attached Schematic 6,335'9-5/8" October 11, 2024 3-1/2" 6,546' Perforation Depth MD (ft): 3,090psi1,007' N/A~2174psi Mid Kenai D, Mid Kenai E & Hemlock Oil Hyd Packer / TE-5 SSSV 364' (MD) 364' (TVD) / 313' (MD) 313' (TVD) 6,448'6,461'6,236' 13-3/8" See Attached Schematic m n P s 66 t V N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:16 am, Sep 30, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.09.27 15:22:15 - 08'00' Dan Marlowe (1267) 324-563 X 10-404 DSR-10/2/24BJM 10/3/24 Provide 48 hrs notice for AOGCC opportunity to witness SSSV testing. SFD 10/4/2024JLC 10/4/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.07 13:37:49 -08'00' 10/07/24 RBDMS JSB 100824 Subsurface controlled SSSV Install Well: Monopod A-02 Well Name: Monopod A-02 API Number: 50-733-10056-00-00 Current Status: Online Oil Well Leg: n/a Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 166-049 First Call Engineer: Ryan Rupert (907) 301-1736 (c) Second Call Engineer: Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP: 2,795 psi @ 6,209’ TVD 0.45psi/ft at Deepest perf Max. Potential Surface Pressure: 2174 psi Using 0.1 psi/ft Brief Well Summary Well A-02 on Monopod as a 3-1/2” Baker TE-5 TRSSSV currently installed. It was run in 2015. The well failed it’s state test recently. Troubleshooting is ongoing, but if unable to reestablish integrity of the TRSSSV, a subsurface controlled SSSV may be required. A lockout + WL-SSSV may be pursued in the future, but those parts are not readily available currently. The goal of this project is to install a subsurface controlled SSSV. Pertinent wellbore information: - Sept-2024: Brushing SSSV, and using Safeacid. Now closing, but not passing PT criteria - March-2024: Brush SSSV. Safe Acid soak across SSSV. Pass - Sept-2023: Brush SSSV. Pass - April-2023: Brush SSSV. Pass - Sept-2022: Brush SSSV. Safe Acid soak across SSSV. Pass - March-2022: Brush SSSV. Acid soak across SSSV. Pass - March-2021: Brush SSSV. Pass - Sept-2020: Brush SSSV. Pass - March-2020: o SSSV won’t close o Brush SSSV o Set AD2 stop / packoff plug, and AA stop from 350 – 324’ MD just below SSSV o Place Safeacid across valve o AA stop and packoff retrieved, AD2 stop won’t pull free. Fish, and can’t get it. o Left AD2 stop at 318’ MD, right below polishbore of SSSV o Got SSSV to close and pass - March-2015 RWO o Ran new ESP with packer completion and 3-1/2’ baker TE-5 TRSSSV o MIT-T against plug at 4495’ MD to 3800psi: PASS o MIT-IA to 1650psi: PASS Subsurface controlled SSSV Install Well: Monopod A-02 SSC-SSSV Suitability Evaluation: Well historic parameters: Production 700 bwpd / 125 bopd / 125mcfd FTP 110 psig Flowing WHT 120 F This safety valve will be setup targeting a trip pressure of ~70 psig. This will be under the well’s normal FTP range of 90-120psi FTP. To test the valve we route it to the separator or flare and lower the FTP to below 60psi thus tripping the valve. Procedure: 1. MIRU Slick-line, PT lubricator to 2,500 psi Hi / 250 Low 2. RIH and set the subsurface controlled subsurface safety valve in profile at 313’ MD 3. Turn well over to production 4. Conduct a SVS test within 5 days after stabilized flow Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Halliburton K-valve Subsurface Safety valve product sheet Updated by: JLL 12/13/22 Trading Bay Unit Well # A-2 Completed: 03/09/15 SCHEMATIC CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8”61 K-55 Butt 12.515 Surf.1,023’ 9-5/8”40 & 43.5 K-55 & N-80 8rd LT&C 8.755 Surf 6,546’ TUBING DETAIL 3-1/2”9.2 L-80 Supermax 2.992 Surf 5,297’ Tubing Punch – 12 each, 0.375 holes -- 5,166’ – 5,168’ JEWELRY DETAIL NO.Depth MD Depth TVD ID Item 42’42’TBG Hanger 1 313’313’2.810 Baker TE-5 SSSV 2 364’364’2.991 Dual String Hydroset Packer w/Vent valve 3 4,495’4,334’2.810 X-Nipple w/ 2.81” profile w/RHCP Plug Installed 4 5,297’5,109’-Bolt-On Discharge 5,298’5,110’-Pump (x3) 5,359’5,169’-Intake 5,378’5,188’-Motor (x2) 5,444’5,252’Centrilizer / Anode Perforation Details Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amount Condition CZN 47-5 4,738'4,767'4,566'4,594'29'Open CZN 48-5 4,833'4,839'4,658'4,664'6'Open CZN 50-0 4,996'5,010'4,816'4,829'14'Open CZN 50-3 5,022'5,048'4,841'4,866'26'Open CZN 50-6 5,088'5,100'4,905'4,917'12'Open CZN 51-0 5,132'5,142'4,948'4,958'10'Open CZN 51-6 5,161'5,223'4,976'5,037'62'Open 5,288'5,290'5,100'5,102'2'Sqz Perfs DZN 53-0 5,298'5,328'5,110'5,139'30'Open DZN 53-0 5,360'5,379'5,170'5,189'19'Open DZN 53-8 5,386'5,434'5,196'5,242'48'Open DZN 53-8 5,400'5,410'5,209'5,219'10'Cmt sqz'd off gas DZN 53-8 5,410'5,430'5,219'5,239'20'Reperf'd Open f/Prod DZN 54-5 5,450'5,480'5,258'5,287'30'Reperf'd Open f/Prod DZN 54-5 5,457'5,478'5,265'5,285'21'Open DZN 54-9 5,494'5,538'5,301'5,344'44'Open DZN 54-9 5,500'5,532'5,307'5,338'32'Reperf'd Open f/Prod DZN 55-7 5,562'5,594'5,367'5,398'32'Open 5,590'5,592'5,395'5,397'2'Sqz Perfs DZN 56-1 5,611'5,698'5,415'5,500'87'Open DZN 56-1 5,630'5,640'5,434'5,443'10'Reperf'd Open f/Prod DZN 56-1 5,660'5,693'5,463'5,495'33'Reperf'd Open f/Prod DZN 57-2 5,728'5,792'5,529'5,592'64'Open DZN 57-2 5,730'5,785'5,531'5,585'55'Reperf'd Open f/Prod EZN 58-1 5,816'5,858'5,615'5,656'42'Open EZN 58-1 5,820'5,825'5,619'5,624'5'Cmt sqz'd off gas EZN 58-1 5,825'5,850'5,624'5,648'25'Open f/Prod EZN 58-7 5,872'5,964'5,670'5,760'92'Open EZN 58-7 5,900'5,960'5,697'5,756'60'Open f/Prod EZN 60-0 5,986'6,007'5,781'5,802'21'Open EZN 60-0 5,990'6,020'5,785'5,814'30'Open f/Prod Hemlock 6,090'6,092'5,883'5,885'2'Sqz Perfs Hemlock 6,110'6,140'5,903'5,932'30'Open f/Prod Hemlock 6,110'6,420'5,903'6,209'310'Open 6,149'6,150'5,941'5,942'1'Erroneously perf'd Hemlock 6,150'6,285'5,942'6,075'135'Open f/Prod Hemlock 6,300'6,420'6,090'6,209'120'Open f/Prod GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,189’2,103’2.992 IPOR-1/IPOC-1/PPOR-1 16 DOME 1000 04/20/2015 2 3,568’3,438’2.992 IPOR-1/IPOC-1/PPOR-1 16 DOME 975 04/20/2015 3 4,448’4,288’2.992 ORIFICE 20 ORIFICE 04/20/2015 Updated by: DMA 09/27/24 Trading Bay Unit Well # A-2 Completed: 03/09/15 PROPOSED CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8”61 K-55 Butt 12.515 Surf.1,023’ 9-5/8”40 & 43.5 K-55 & N-80 8rd LT&C 8.755 Surf 6,546’ TUBING DETAIL 3-1/2”9.2 L-80 Supermax 2.992 Surf 5,297’ Tubing Punch – 12 each, 0.375 holes -- 5,166’ – 5,168’ JEWELRY DETAIL NO.Depth MD Depth TVD ID Item 42’42’TBG Hanger 1 313’313’2.810 Baker TE-5 SSSV –SSC - SSSV 2 364’364’2.991 Dual String Hydroset Packer w/Vent valve 3 4,495’4,334’2.810 X-Nipple w/ 2.81” profile w/RHCP Plug Installed 4 5,297’5,109’-Bolt-On Discharge 5,298’5,110’-Pump (x3) 5,359’5,169’-Intake 5,378’5,188’-Motor (x2) 5,444’5,252’Centrilizer / Anode Perforation Details Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amount Condition CZN 47-5 4,738'4,767'4,566'4,594'29'Open CZN 48-5 4,833'4,839'4,658'4,664'6'Open CZN 50-0 4,996'5,010'4,816'4,829'14'Open CZN 50-3 5,022'5,048'4,841'4,866'26'Open CZN 50-6 5,088'5,100'4,905'4,917'12'Open CZN 51-0 5,132'5,142'4,948'4,958'10'Open CZN 51-6 5,161'5,223'4,976'5,037'62'Open 5,288'5,290'5,100'5,102'2'Sqz Perfs DZN 53-0 5,298'5,328'5,110'5,139'30'Open DZN 53-0 5,360'5,379'5,170'5,189'19'Open DZN 53-8 5,386'5,434'5,196'5,242'48'Open DZN 53-8 5,400'5,410'5,209'5,219'10'Cmt sqz'd off gas DZN 53-8 5,410'5,430'5,219'5,239'20'Reperf'd Open f/Prod DZN 54-5 5,450'5,480'5,258'5,287'30'Reperf'd Open f/Prod DZN 54-5 5,457'5,478'5,265'5,285'21'Open DZN 54-9 5,494'5,538'5,301'5,344'44'Open DZN 54-9 5,500'5,532'5,307'5,338'32'Reperf'd Open f/Prod DZN 55-7 5,562'5,594'5,367'5,398'32'Open 5,590'5,592'5,395'5,397'2'Sqz Perfs DZN 56-1 5,611'5,698'5,415'5,500'87'Open DZN 56-1 5,630'5,640'5,434'5,443'10'Reperf'd Open f/Prod DZN 56-1 5,660'5,693'5,463'5,495'33'Reperf'd Open f/Prod DZN 57-2 5,728'5,792'5,529'5,592'64'Open DZN 57-2 5,730'5,785'5,531'5,585'55'Reperf'd Open f/Prod EZN 58-1 5,816'5,858'5,615'5,656'42'Open EZN 58-1 5,820'5,825'5,619'5,624'5'Cmt sqz'd off gas EZN 58-1 5,825'5,850'5,624'5,648'25'Open f/Prod EZN 58-7 5,872'5,964'5,670'5,760'92'Open EZN 58-7 5,900'5,960'5,697'5,756'60'Open f/Prod EZN 60-0 5,986'6,007'5,781'5,802'21'Open EZN 60-0 5,990'6,020'5,785'5,814'30'Open f/Prod Hemlock 6,090'6,092'5,883'5,885'2'Sqz Perfs Hemlock 6,110'6,140'5,903'5,932'30'Open f/Prod Hemlock 6,110'6,420'5,903'6,209'310'Open 6,149'6,150'5,941'5,942'1'Erroneously perf'd Hemlock 6,150'6,285'5,942'6,075'135'Open f/Prod Hemlock 6,300'6,420'6,090'6,209'120'Open f/Prod GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,189’2,103’2.992 IPOR-1/IPOC-1/PPOR-1 16 DOME 1000 04/20/2015 2 3,568’3,438’2.992 IPOR-1/IPOC-1/PPOR-1 16 DOME 975 04/20/2015 3 4,448’4,288’2.992 ORIFICE 20 ORIFICE 04/20/2015 • • otqg Schwartz, Guy L (DOA) `� From: Schwartz, Guy L(DOA) Sent: Wednesday, February 24, 2016 12:55 PM To: 'Juanita Lovett';Trudi Hallett Cc: samantha.carlisle@alaska.gov Subject: RE: Please withdraw Sundry#315-231/ PTD: 166-049 - Monopod A-02 Juanita, Sundry 315-231 will be withdrawn as requested. Guy Schwartz p AUG A `Z016 Sr. Petroleum Engineer SCOSE AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Juanita Lovett [mailto:jlovett@hilcorp.com] Sent: Wednesday, February 24, 2016 12:39 PM To: Schwartz, Guy L (DOA); Trudi Hallett Subject: Please withdraw Sundry # 315-231 / PTD: 166-049 - Monopod A-02 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: iIovett@hilcorp.com 1 RBDMS F03 2 5 2016 v T� w \C41:1\ �/yi�sr THE STATE Alaska Oil and Gas .t.,....- -44-,._;.%,-,;1,- ofALASKA Conservation Commission '. i itt_ 333 West Seventh Avenue ' j GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF ;,^ � Main. 907.279.1433 ALAS'' Fax: 907.276.7542 www.aogcc alaska.gov SCANNED APR 2 4 2015 Dan Marlowe /� Operations Engineer Q t j Hilcorp Alaska, LLC t 64 .-- 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C, D & E and Hemlock Oil Pools, Trading Bay St A-02 Sundry Number: 315-231 Dear Mr. Marlowe: 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, i°91,A.41-1--.. Cathy P. oerster Chair DATED this Z day of April, 2015 Encl. STATE OF ALASKA '1 P R 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,AOGCC 20 MC 25.280 _ 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well LS!c,1— Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 0. Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Replace ESP 0 . 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 0 • 166-049 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic El Service ❑ 6.API Number. Anchorage,AK 99503 50-733-10056-00 • 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay St A-02 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 r Trading Bay Field/Middle Kenai C,Middle Kenai D,Middle Kenai E&Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): -6,669 • 6,448 , 6,461 ' 6,236 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,023' 13-3/8" 1,023' 1,007' 3,090 psi 1,540 psi Intermediate Production 6,546' 9-5/8" 6,546' 6,335' 3,950 psi 2,570 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 5,297' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Hyd Packer/TE-5 SSSV ' 364'(MD)364'(ND)/313'(MD)313'(ND) 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/23/2015 Commencing Operations: Oil 0• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true,and correct to the best of my knowledge. Contact Dan Marlowe Z' - - Title Operations Engineer J Signatur- Phone (907)283-1329 Date 4/20/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number `S _ 23l Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ 7 Other: j� F� ( 44.S 4 zC1 t, 2-p 5...) t�" z. S s Spacing Exception Required? Yes ❑ No Subsequent Form Required: / b -/pi..( ale APPROVED BY Approved by: 4„1 � COMMISSIONER THE COMMISSION Date: 4_24_/5- 4)1 •1— Form e/�J/fl�c— II j , � n I---1)1416 /� ( Submit Form and Form 10-403(Revised 10/2012)4. QR vk p�c '-nl�y for 12 months from the date of approv I. Attachments in Duplicate RBDM �1' APR 2 2 2015 Well Prognosis Well: A-02 aeeury Alaska.1.1. Date:04/20/2015 Well Name: Monopod A-02 API Number: 50-733-10056-00 Current Status: Oil producer(ESP) Leg: N/A Estimated Start Date: 04/23/2015 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 166-049 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 2,659 psi @ 5,986' (5,781' TVD) From downhole gauge on ESP Maximum Expected BHP: 2,659 psi @ 5,986' (5,781' TVD) From downhole gauge on ESP Max. Anticipated Surface Pressure: 2,062 psi (Using a 0.1 psi/ft gradient per 20 AAC 25.280 (b)(4) Brief Well Summary The A-02 well is currently completed with an ESP which failed on 04/19/15.This work over will replace the failed pump. Last Casing Test: 11/25/14 4,705' 1560 psi on chart for 30 minutes. Brief Procedure: 1. MIRU Monopod Platform Rig#56. 2. Kill well and circulate Hydrocarbon off of well with 3% KCL through ESP. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE.Test all BOP equipment per AOGCC guidelines to 250psi low and 2,500psi high. 4. Monitor well to ensure it is static. 5. Unseat hanger and high set packer, POOH with ESP. 6. PU and RIH with new ESP assembly consisting of the ESP, Packer, GLMs, Packer Vent Valve, SSSV. 7. Set bottom of ESP @ +/- 5,444'. Set packer @ +/- 364'. Pressure test to 1,500 psig and chart for 30 min. 8. ND BOP, NU wellhead and test. 9. Turn well over to production. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. BOP Drawing 4. Wellhead Schematic Current/ Proposed (Same) Trading Bay Unit . ti SCHEMATIC Well #A-2 Completed: 03/09/15 RKB to TBG Hngr=36.40' CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 2 13-3/8" 61 K-55 Butt 12.515 Surf. 1,023' 9-5/8" 40&43.5 K-55&N-80 8rd LT&C 8.755 Surf 6,546' TUBING DETAIL 3-1/2" 9.2 L-80 Supermax 2.992 Surf 5,297' L I i, 3 JEWELRY DETAIL NO. Depth ID Item 42' TBG Hanger 1 313' 2.810 Baker TE-5 SSSV 2 364' 2.991 Dual String Hydroset Packer w/Vent valve 43 2,189' 2.992 GLM 4 3,568' 2.992 GLM 5 4,448' 2.992 GLM 6 4,495' 2.810 X-Nipple w/2.81"profile w/RHCP Plug Installed > 5 ICS 6 7 5,297' - Bolt-On Discharge CZN 47-5 CZN 48-5 CZN 50-0 8 5,298' - Pump(x3) 9 5,359' - Intake 10 5,378' Motor(x2) 11 5,444' Centrilizer/Anode - CZN 50-3 C• ZN 50-6 C• ZN 51-0 CZN 51-6 Perforation Details Cg D• ZN 53-0 Top Btm Top Btm Q DZN53-8 Zone (MD) (MD) (TVD) (TVD) Amount Condition CZN 47-5 4,738' 4,767' 4,566' 4,594' 29' Open n DZN 545 CZN 48-5 4,833' 4,839' 4,658' 4,664' 6' Open = DZN 549 CZN 50-0 4,996' 5,010' 4,816' 4,829' 14' Open N DZN 55-7 CZN 50-3 5,022' 5,048' 4,841' 4,866' 26' Open CZN 50-6 5,088' 5,100' 4,905' 4,917' 12' Open DZN56-1 CZN 51-0 5,132' 5,142' 4,948' 4,958' 10' Open CZN 51-6 5,161' 5,223' 4,976' 5,037' 62' Open 5,288' 5,290' 5,100' 5,102' 2' Sqz Perfs a DZN 57-2 DZN 53-0 5,298' 5,328' 5,110' 5,139' 30' Open DZN 53-0 5,360' 5,379' 5,170' 5,189' 19' Open - Eh DZN 53-8 5,386' 5,434' 5,196' 5,242' 48' Open EZN 58 1 DZN 53-8 5,400' 5,410' 5,209' 5,219' 10' Cmt sqz'd off gas DZN 53-8 5,410' 5,430' 5,219' 5,239' 20' Reperfd Open f/Prod DZN 54-5 5,450' 5,480' 5,258' 5,287' 30' Reperf'd Open f/Prod EZN 58 7 DZN 54-5 5,457' 5,478' 5,265' 5,285' 21' Open 7 = DZN 54-9 5,494' 5,538' 5,301' 5,344' 44' Open $ =EZN 60-0 DZN 54-9 5,500' 5,532' 5,307' 5,338' 32' Reperf'd Open f/Prod _: 9 DZN 55-7 5,562' 5,594' 5,367' 5,398' 32' Open 5,590' 5,592' 5,395' 5,397' 2' Sqz Perfs CP 111 10 DZN 56-1 5,611' 5,698' 5,415' 5,500' 87' Open 11 DZN 56-1 5,630' 5,640' 5,434' 5,443' 10' Reperfd Open f/Prod DZN 56-1 5,660' 5,693' 5,463' 5,495' 33' Reperfd Open f/Prod DZN 57-2 5,728' 5,792' 5,529' 5,592' 64' Open DZN 57-2 5,730' 5,785' 5,531' 5,585' 55' Reperf'd Open f/Prod - Hemlock EZN 58-1 5,816' 5,858' 5,615' 5,656' 42' Open EZN 58-1 5,820' 5,825' 5,619' 5,624' 5' Cmt sqz'd off gas EZN 58-1 5,825' 5,850' 5,624' 5,648' 25' Open f/Prod EZN 58-7 5,872' 5,964' 5,670' 5,760' 92' Open EZN 58-7 5,900' 5,960' 5,697' 5,756' 60' Open f/Prod EZN 60-0 5,986' 6,007' 5,781' 5,802' 21' Open EZN 60-0 5,990' 6,020' 5,785' 5,814' 30' Open f/Prod KB ELEV=101' Hemlock 6,090' 6,092' 5,883' 5,885' 2' Sqz Perfs PBTD=6,461' Hemlock 6,110' 6,140' 5,903' 5,932' 30' Open f/Prod ANGLE thrU INTERVAL=12.7° Hemlock 6,110' 6,420' 5,903' 6,209' 310' Open 6,149' 6,150' 5,941' 5,942' 1' Erroneously perfd Hemlock 6,150' 6,285' 5,942' 6,075' 135' Open f/Prod Hemlock 6,300' 6,420' 6,090' 6,209' 120' Open f/Prod Updated by: JLL 04/02/15 Trading Bay Unit PROPOSED Well #A-2 Completed: Future RKB to TBG Hngr=36.40' CASING DETAIL 1, SIZE WT GRADE CONN ID TOP BTM. 1 , 13-3/8" 61 K-55 Butt 12.515 Surf. 1,023' , ' 2 9-5/8" 40&43.5 K-55&N-80 8rd LT&C 8.755 Surf 6,546' TUBING DETAIL 3 3-1/2" 9.2 L-80 Supermax 2.992 Surf ±5,297' L i 3 JEWELRY DETAIL NO. Depth ID Item 1 42' TBG Hanger x ? Monopod Platform A-2 Current ESP 12/08/2014 II.Irnrp:%In.ka.i.1A. Monopod Platform Tubing hanger,CIW-DCB-ESP, A-2 11 X 3'/:EUE lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 3"type H BPV profile,5'/.EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union I ,. f III 11.1 RIM fly iiiit I.. Valve,swab,WKM-M, 3 1/8 5M FE,HWO, -: I - T-24 •0 o .., .. Valve,WKM-M,3 1/8 5M FE,w/ MA-16 operator Valve,wing,WKM-M, 2 1/16 5M FE,HWO, 1 ),,,_) VII iii ©) T-24 �. i° Valve,lower master,WKM-M, _. 3 1/8 5M FE,HWO,T-24 < ,.,MIMI. lifl -" Adapter,CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE,prepped for -. 5'/.ESP neck,2-1/2 npt continuous jcontrol line ports Tubing head,CIW-DCB, ,M — •—rte . 13 5/8 3M X 115M,w/ _.c1 , - i'i.__ 2- 1/16 5M SSO, _ - X bottom lei �, I Valve,WKM-M,2 1/16 5M FE, Replaced tubing head c , 4 HWO,DD 2014 �— �� ..,,---, 1,10._,.,, III 1.1 Casing head, Shaffer KD, 13 3/8 SOW,w/2-2' I I I -' III 2"LP CIW ball valve LPO, 0}.0 .. ii Monopod Platform 2014 BOP Stack(A-2) 10/23/2014 Hilrrurp Alaska,I l L ige Bottom of air boot flange Rig Floor A 5'below rig floor 16" 13.01' vice 111 III II! ,11.111 F M as a • 4.54' grit 0_ I iii Iii III 26.25' 2 3/8 t 314 Dual Flet rams CIW-ll 'I- _- it I, 135/85M "II. lasBlind tilin)/(i ih 21/165M manual and 2 1/16 5M manual and 1.76' NCR valves for r oke side I I 1 1 I 1 I L HCR valves for kill side I (I V .lii� Tii ii.l�i1`i.1 ./4�•©Il al Shaffer SL 22/8-S.5 Variables 1,44' 135/85M . -1i * I1 - 111,iff.i Ii,1 Ii III 4 Drill deck Riser 135/8 SM FEX 13 S/I SM FE 11.OD' 1 1(D. etthrtutha U 4D4JJ(Di i) Spacer spool 3.00• 13 5/8 SM FE if 135/85M FE '1:' :111 1111 11 :1 IAt III 111 spoof _ 1.n 1' 3M iEX '11 I I.Ill III STATE OF ALASKA RECEIVED AL A OIL AND GAS CONSERVATION COME ,ON REPORT OF SUNDRY WELL OPERATIONS , : ...P °1��.):= SIJ [)R'( 1.Operations Abandon LI Repair Well Cl Plug Perforations 0 Perforate❑ OtM� DGCGSP Performed: Alter Casing❑ Pull Tubing Stimulate-Frac 0 Waiver ❑ Time Extension Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Name: Development CI Exploratory❑ 166-049 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,Alaska 99503 50-733-10056-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Trading Bay Field/Middle Kenai C,Middle Kenai D and E&Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 6,669 feet Plugs measured N/A feet true vertical 6,448 feet Junk measured N/A feet Effective Depth measured 6,461 feet Packer measured 364 feet true vertical 6,236 feet true vertical 364 feet Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,023' 13-3/8" 1,023' 1,007' 3,090 psi 1,540 psi Intermediate Production 6,546' 9-5/8" 6,546' 6,335' 3,950 psi 2,570 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED APR 242015 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 5,297'(MD) 5,109'(ND) Packers and SSSV(type,measured and true vertical depth) Hyd.Pkr 364'(MD)364'(TVD) TE-5 SSSV 313'(MD)313'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 145 185 1370 220 240 Subsequent to operation: 554 1273 2544 220 240 . 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas El WDSPL❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ 3USP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-077 Contact Trudi Hallett Email thallett( hilcorD.com Printed Name Trudi Hallett Title , ; , Operations Engineer fitA1Signature 46 ialit'et- , Phone 907-777-8323 Date 4/2/2015 y.,�,_,s RBDMS. ' APR - 6 2015 Form 10-404 Revised 10/2012 , ./t... Submit Original Only el/�-// Trading Bay Unit rd. SCHEMATIC Well#A-2 Completed: 03/09/15 RKB to TBG Hngr=36.40' CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61 K-55 Butt 12.515 Surf. 1,023' 2 9-5/8" 40&43.5 K-55&N-80 8rd LT&C 8.755 Surf 6,546' TUBING DETAIL 3-1/2" 9.2 1-80 Supermax 2.992 Surf 5,297' L 3 JEWELRY DETAIL NO. Depth ID Item 42' TBG Hanger 1 313' 2.810 Baker TE-5 SSSV 2 364' 2.991 Dual String Hydroset Packer w/Vent valve 4 3 2,189' 2.992 GLM 4 3,568' 2.992 GLM 5 4,448' 2.992 GLM 6 4,495' 2.810 X-Nipple w/2.81"profile w/RHCP Plug Installed ma 0 5 7 5,297' - Bolt-On Discharge #:t 6 8 5,298' - Pump(x3) FE CZN 47-5 9 5,359' - Intake = CZN 48-5 10 5,378' - Motor(x2) CZN 50-0 11 5,444' Centrilizer/Anode = CZN 50-3 = CZN 50-6 = CZN 51-0 CZN 51-6 Perforation Details tx Top Btm Top Btm DZN 53-0 Zone Amount Condition (MD) (MD) (TVD) (TVD) - DZN53-8 CZN 47-5 4,738' 4,767' 4,566' 4,594' 29' Open DZN 545 CZN 48-5 4,833' 4,839' 4,658' 4,664' 6' Open mi DZN 549 CZN 50-0 4,996' 5,010' 4,816' 4,829' 14' Open 11 DZN 55-7 CZN 50-3 5,022' 5,048' 4,841' 4,866' 26' Open CZN 50-6 5,088' 5,100' 4,905' 4,917' 12' Open DZN56-1 CZN 51-0 5,132' 5,142' 4,948' 4,958' 10' Open CZN 51-6 5,161' 5,223' 4,976' 5,037' 62' Open ll 5,288' 5,290' 5,100' 5,102' 2' Sqz Perfs MI DZN 57-2 DZN 53-0 5,298' 5,328' 5,110' 5,139' 30' Open = DZN 53-0 5,360' 5,379' 5,170' 5,189' 19' Open CE DZN 53-8 5,386' 5,434' 5,196' 5,242' 48' Open EZN 58-1 DZN 53-8 5,400' 5,410' 5,209' 5,219' 10' Cmt sqz'd off gas DZN 53-8 5,410' 5,430' 5,219' 5,239' 20' Reperfd Open f/Prod DZN 54-5 5,450' 5,480' 5,258' 5,287' 30' Reperfd Open f/Prod E EZN 58-7 DZN 54-5 5,457' 5,478' 5,265' 5,285' 21' Open - 7 DZN 54-9 5,494' 5,538' 5,301' 5,344' 44' Open 8 =EZN 60-0 DZN 54-9 5,500' 5,532' 5,307' 5,338' 32' Reperfd Open f/Prod 9 DZN 55-7 5,562' 5,594' 5,367' 5,398' 32' Open 5,590' 5,592' 5,395' 5,397' 2' Sqz Perfs cc 10 DZN 56-1 5,611' 5,698' 5,415' 5,500' 87' Open 11 DZN 56-1 5,630' 5,640' 5,434' 5,443' 10' Reperfd Open f/Prod DZN 56-1 5,660' 5,693' 5,463' 5,495' 33' Reperfd Open f/Prod DZN 57-2 5,728' 5,792' 5,529' 5,592' 64' Open DZN 57-2 5,730' 5,785' 5,531' 5,585' 55' Reperfd Open f/Prod = Hemlock EZN 58-1 5,816' 5,858' 5,615' 5,656' 42' Open EZN 58-1 5,820' 5,825' 5,619' 5,624' 5' Cmt sqz'd off gas EZN 58-1 5,825' 5,850' 5,624' 5,648' 25' Open f/Prod EZN 58-7 5,872' 5,964' 5,670' 5,760' 92' Open EZN 58-7 5,900' 5,960' 5,697' 5,756' 60' Open f/Prod EZN 60-0 5,986' 6,007' 5,781' 5,802' 21' Open EZN 60-0 5,990' 6,020' 5,785' 5,814' 30' Open f/Prod KB ELEV=101' Hemlock 6,090' 6,092' 5,883' 5,885' 2' Sqz Perfs PBTD=6,461' Hemlock 6,110' 6,140' 5,903' 5,932' 30' Open f/Prod ANGLE thru INTERVAL=12.7° Hemlock 6,110' 6,420' 5,903' 6,209' 310' Open 6,149' 6,150' 5,941' 5,942' 1' Erroneously perfd Hemlock 6,150' 6,285' 5,942' 6,075' 135' Open f/Prod Hemlock 6,300' 6,420' 6,090' 6,209' 120' Open f/Prod Updated by: JLL 04/02/15 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 3/4/15 3/9/15 Daily Operations: 03/04/15-Wednesday Nip/dn&remove tree. Chk hanger(ok)dress hanger control lines and penetrator. M/up test jt w/blanking plug&and get measurements. L/dn test jt. 20"X 13-3/8"=0 psi, 13-3/8"X 9-5/8"=0 Psi. Daily brine lost to well= 155 bbls.Total brine lost t/well =1095 bbls. Daily sized salt to well=0 bbls.Total SS to well=160 bbls. Set riser nip/up BOPE's. Charge up Koomey unit. Function test BOPE's. Test BOPE's aser AOGCC regulations 250-2500 psi on 2-7/8"and 3-1/2"test jts with 0 failures.Witness waived By Mr. Regg on 3/2/15 @ 11: 02 AM. Back out blanking sub. Rig down and lay down test equipment. PU T-Bar and sting into BPV and vent gas/oil from below BPV. Unsting from BPV,set T-bar aside. Close Blinds Rams. Pump through down tubing through BPV to Kill tubing below BPV. Had to pump a total of 120 bbls through BPV. Pull BPV. Close Blind rams and monitor well with 50 psi build in 30 minutes. Lube and Bleed additional 50 bbls at 10 bbl increments.Open choke and circulate charge pump across top of tbg to pits monitoring fluid loss/gain and establish 18-20 bph loss rate. MU Landing joint to hanger. MU Top drive to landing joint. RU circulating hose on 9 5/8"annulus to production low pressure header.Tubing increased to 160 psi. Pump 26 bbls tubing volume w/350 psi. BOLDS,unseat PKR and Hgr. @ 130K. Up wt 95K when unseated. Bring on pump and sweep well to production circulating through GLM @ 352'. Pump total of 55 bbls. Bleed off tubing,shut in well,slack off and re-land tubing hanger to rig up slick line. 03/05/15-Thursday R/up slick line.Test lubricator t/250-2000 psi(ok).Open tbg w/100 psi. Rih w/Daniels kick over tool&set valve in GLM @ 352'. POOH(Valve set) R/dn slick line. Pull hanger back off seat and up into riser 5' with 85k traveling up wt. Pump dn tbg @ 2 bpm taking returns off annulus and sweep oil cap to production.Oil returns @ 165 bbls away. Pump total 310 bbls. Pump 40 bbls sized salt pill and chase w/8 bbls brine.Shut returns to production and monitor annulus pressure keeping tbg full w/charge pump. Monitoring loss rate 86>26 bph and let pill soak while building SS pill and waiting on boat w/ more product for 9.5 ppg brine volume. 20"X 13-3/8" =0 psi, 13-3/8"X 9-5/8"=0 Psi. Daily brine lost to well=491 bbls. Total brine lost t/well=1585 bbls. Daily sized salt to well=42 bbls.Total SS to well=202 bbls. Pump 2 bpm and sweep gas/oil cap to production w/gas returns for first(5) bbls,then oil for 23 bbls,then brine back pump total 30 bbls dn pump. Attempt circ dn tbg thru wide open choke @ 4 bpm.Tbg pressure increased t/1150 psi w/no returns dn pump(pkr element energizing and bull heading). Pull prk up hole 2' @ 35k over and brk circ @ 2 bpm at 105 bbls away lot gas up foamy brine w/high gas of 7760 units.Was able to brk it w/defoamer(foam disappeared 3/4 the way around). Finished circ complete round w/loss rate while circ @ 50>33 bph(build 9.5 ppg volume). Open annular circ btm/up @ 2 bpm @ 500 psi.Continue build volume w/loss rate+40 bph and gas units dn to+/-30 units. Circ across top establish static loss @ 21.5 bph. Break off Top Drive with tubing out of balance. Pump additional 50 bbls to balance tubing. Pull tubing hanger to floor breaking down and laying down 3 1/2" IF landing joint. Remove cable and flat pack lines. Lay down tubing hanger. Hold PJSM on POOH with ESP. POOH with ESP completion laying down 6 joints 2 7/8"tubing to 5,895'. Rig up ESP and Flat Pack sheaves.Continue to POOH with ESP completion laying down SSSV, PKR,X Nipple and GLM to 5,730'. Rig up circulating hose.Circulate hole clean from tubing punch @ 4,362' @ 9 BPM with 2780 psi. Hole cleaned up at 370 bbls pumped. Rig down and blow down circulating hose. Continue to POOH with ESP completion cleaning and laying down 2 7/8"tubing form 5,730'to 3,977'. (66 jts and all jewelry). , . Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 3/4/15 3/9/15 Daily Operations: 03/06/15-Friday Continue POOH L/dn and inspect completion. Noticed ID scale starting about 1/2 way&getting thicker to pump @ +/-1/6". No OD scale noticed up to 5,579'then all at once solid scale up to 1"+thick f/5,579't/5,673'( Perf interval DZN56-1, DZN 55-7). Normed hot @ 47 micro/rim/hr(wet) f/5,673'to ESP. Note: scale was attached to everything except flat pack rubber coating.Samples have been gathered and will be sent to Mr. Ping,also 15%acid tests preformed w/no reaction. Loss @ 18-20 bph(Total of 11 jts isolated with various amount OD scale).As pipe has dried out norm levels have risen to+/- 100 Micro/rim/hr. L/dn clean and inspect ESP assy w/full recovery. Mtr clamps had corrosion to point that a couple had holes. Discharge head full of scale&pump locked up.Top seal had water, middle dry gassy, btm good.Anode still there but a lot of use. 20"X 13-3/8" =0 psi, 13-3/8"X 9-5/8" =0 Psi. Daily brine lost to well=448 bbls.Total brine lost t/well=2033 bbls. Daily sized salt to well =0 bbls.Total SS to well=202 bbls. Clear and clean floor and work areas. Make up clean out BHA#1 as follows: 8.5" Bit(20 Jets), Boot Basket, 9 5/8"OD casing scraper, Boot Basket, Boot Basket, Bit Sub W/FLOAT, String Magnet, Cross Over, Bumper Sub, Oil Jars, 6)4 3/4" Drill Collar, Accel Jar.Total BHA Length=247.45'. TIH with C/O assembly on 3 1/2" DP from 247'to 4,500'. Continue to TIH 4,500'to 5,250'. Assist crane crew working Boat. Set Wear Bushing. 16 BPH Static Loss. Work boat rack and tally 2 7/8"super Max tubing. Fill pipe and CBU at 9 bpm, 1550 psi,97K Up Wt,80K Dn Wt. No gas or debris at bottoms up. CBU at 9 bpm, 1750 psi, 110K Up Wt,85K Dn Wt. No gas or debris at bottoms up. Pump 400 bbls with 13 BPH. RIH to 6,430' MU Top Drive. Wash down from 6,430',tag and wash through fill at 6,450'. Tag PBTD @ 6,461'with 10K down.Circulate hole clean @10 BPM with 2800 psi, Pu Wt 130K, Dn Wt 95K, Max gas @ 1700u. Had sand and salt @ bottoms up. Under 1 bbl solids for entire trip and circulations. 13 BPH loss rate @ 10 bpm. Blow down top drive and obtain static loss rate at 15 BPH. POOH standing back 3 1/2" drill pipe from 6,450' to 3,000'. Hourly loss rate @ 15.5 bph. 03/07/15-Saturday Continue POOH standing back dp t/Bha#1. L/dn jars and std back dc's&clean string magnet and recover 45#iron. Brk/dn and clean J-bsk. Recovered 56#sand. L/dn same.Clear floor and door static loss @ 12 bph and prep to run tbg. Service rig. Make up collar mule shoe. RIH picking up 3 1/2",9.3#, L-80,Super Max tubing from surface to 5,190'. (156 jts 52 stds). Wash down from 6,400',tag PBTD @ 6,461'.Circulate hole volume @ 10 bpm with 1450 psi and 229 units max gas @ bottoms up with 15 BPH loss rate while circulating. Continue to circulate 5 bpm with 385 psi.while waiting on weather to off load the boat of ESP equipment. (high winds). Break off and blow down TDS.Static loss rate @ 14 BPH. POOH standing back 3 1/2" Drill pipe and DC,s on ODS.Continue POOH Stand back 3 1/2"tubing on DS.Static loss @ 12-14 BPH. (1 Hr Day light savings time). PJSM, RU and PU ESP Assembly. 20"X 13-3/8"=0 psi, 13-3/8"X 9-5/8"=0 Psi. Daily brine lost to well =369 bbls.Total brine lost t/well=2402 bbls. Daily sized salt to well=0 bbls.Total SS to well=202 bbls. Cross over to 3 1/2" IF.TIH with 2)stds DC's and 11)stds drill pipe from 5,190'to 6,400'. PULL WEAR BUSHING. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 3/4/15 3/9/15 Daily Operations: 03/08/15-Sunday Continue building in hole ESP assy. Losses @ +/-13 bph. PJSM. Review bare pipe shut in procedure. RIH w/ESP assy 3-1/2" 9.2#L-80 super max tbg out of derrick installing cannon clamps on every conn&mid jt to cover t/top of perfs @ 4,700'. Then one on every conn to surface and meg testing cable every+/-1,000'losses @+/-13 bph. Installed 2nd annulus valve on well head and tested valve. M/up t/250-5000 psi ok(VR plug still installed). Ran from 181'to 2,179'. 20"X 13-3/8"=0 psi, 13-3/8"X 9-5/8"=0 Psi. Daily brine lost to well =302 bbls.Total brine lost t/well=2704 bbls. Daily sized salt to well=0 bbls.Total SS to well=202 bbls. Continue RIH with ESP completion from 2,179'to 5,061'as per tally. PU Tri point 9 5/8" retrievable dual string pkr. Make splice through pkr. Hook up control lines and vent tool. PU and RIH with jt 146. PU SSSV, hook up control lines. Function SSSV with movement @ 1000 psi. Full open at 1200 psi.Test to 5000 psi for 10 min. Continue to RIH with ESP from 5,133'to 5,400'. Pick up and Make up tubing hanger. Make final splice for penetrator. Loss Rate @ 13 BPH. 03/09/15-Monday Finish penetrator splice and dress hanger w/penetrator,chemical and control lines and testing all(ok). Pull VR plug. Land hanger w/anode @5,444'__(up/dn/wt pipe only=55/47k) R.I.L.D.S. Pack off well head.Test cable(ok).20"X 13-3/8"=0 psi, 13-3/8"X 9-5/8"=0 Psi. Daily brine lost to well=135 bbls.Total brine lost t/well=2839 bbls. Daily sized salt to well=0 bbls.Total SS to well=202 bbls. Drop bar. Pressure up on tbg t/3800 psi w/4.6 bbls for 30 min w/#2 MP(good).Set prk @ 364'. Bleed off pressure. W/tbg and SSSV open. Pressure up on annulus w/10 bbls and test csg and prk f/1680 psi t/1670 psi in 30 min on chart(ok). L/dn landing jt and set BPV. R/dn tbg tongs and remove storm clamps and rigs flow lines. Nip/off BOPE's and trolley to the side and remove drilling riser. Land Tree. Prep and skid rig.Continue N/U Tree while skidding the rig.Test void to 250/5000 psi.Test Tree to same holding test for 10 min. Pull TWC.Assist Production on N/U and Tie in of SSV/Wing section. Rig released from A-02 @ 2400 hrs. (COT) 1�7/ sTHE STATE Alaska Oil and Gas ofALAS� Conservation Commission -�--�_� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALA61 Fax. 907.276.7542 www.aogcc.alaska.gov Trudi Hallett Operations Engineer Hilcorp Alaska, LLC (9 - 0 (4-ci 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Trading Bay/Hemlock Oil, Middle Kenai B, C, D, E Oil Pools, Trading Bay ST A-02 Sundry Number: 315-077 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, /c3C44(4,_ Cathy P. F erster Chair DATED this / day of February, 2015 Encl. RECEIVED STATE OF ALASKA FEB 1 1 2015 p73" Zi!rl 1.S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCsC 2Q AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill Cl Perforate New Pod❑ Repair Well VCR" Change Approved Program❑ Suspend El Plug Perforations El Perforate❑ Pull Tubing 0 ' Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ After Casing❑ Other. Install ESP 0. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 166-049 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ 6.API Number. Anchorage,AK 99503 50-733-10056-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? WA v Will planned perforations require a spacing exception? Yes ❑ No Cl Trading Bay St A-02 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 • Trading Bay Field/Middle Kenai C,Middle Kenai D,Middle Kenai E&Hemlock Oil Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): . 6,669 , 6,448 , 6,461 , 6,236 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,023' 13-3/8" 1,023' 1,007' 3,090 psi 1,540 psi Intermediate Production 6,546' 9-5/8" 6,546' 6,335' 3,950 psi 2,570 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" 6.5#/L-80 6,094 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Hyd Packer&BTE-5TR SSSV ' 319'(MD)319'(ND)&295'(MD)295'(MD) 12.Attachments: Description Summary of Proposal 0 . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/1/2015 Commencing Operations: Oil 0• Gas El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallettahilcorq.com Printed Name Trudi Hallett Title Operations Engineer Signature Phone (907)777-8323 Date 2/11/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 15 - 077 Plug Integrity ❑ BOP Test I2r Mechanical Integrity Test ❑ Location Clearance CIOther: 2-500/15 620P ;:; F ( A✓ �S14 ' Z-06,4 p-s0 Spacing Exception Required? Yes ❑ No Subsequent Form Required: k:),— ` Oil aieAPPROVED BY o Approved by: t7"1-4) COMMISSIONER THE COMMISSION Date:Z��D -1 5 Z.rz-1 '4' �► ,do. � 2-/S/S /nor n ❑ 11:G414446 Submn Fonn ane Fonn 10-403(Revised 10/2012) Apvd•d13(`d 12 months from the date of approval. Attachments in Duplicate RBDRISCA FEB 2 3 2015 Well Prognosis • Well: A-02 llileorp Alaska.LL Date:02/11/2015 Well Name: Monopod A-02 API Number: 50-733-10056-00 Current Status: Oil producer(Gas Lifted) Leg: N/A Estimated Start Date: 04/01/2015 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 166-049 First Call Engineer: Trudi Hallett (907) 777-8323 (907) 301-6657 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 (M) Current Bottom Hole Pressure: 2,659 psi @ 5,986' (5,781' TVD) From downhole gauge on ESP Maximum Expected BHP: 2,659 psi @ 5,986' (5,781' TVD) From downhole gauge on ESP Max.Anticipated Surface Pressure: 45.7 psi. (Using a .1 psi/ft gradient per 20 AAC 25.280 (b)(4) Brief Well Summary -2( cc - 'c•c ° `r The A-02 well is currently completed with an undersized ESP. The re-completion plan involves pulling the existing ESP completion, clean out well to the PBTD of 6,461'. The well will then be re-completed with new ESP completion with high set pac Brief Procedure: 1. MIRU Monopod Platform Rig#56. 2. Kill well and circulate Hydrocarbon off of well with 3% KCL through ESP. 3. ND wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness testj: 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP. 6. PU 9-5/8"C/O assembly. RIH to tag for fill or to PBTD of 6,461'. POOH with C/O Assembly. 7. PU and RIH with new ESP assembly consisting of the ESP, Packer,GLMs, Packer Vent Valve,SSSV. 8. Set bottom of ESP @ +/-6,100'. Set packer @+/-350'. Pressure test to 5.011nsig ancl chart for 30 min. 9. ND BOP, NU wellhead and test. 10. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Proposed Wellhead. Trading Bay Unit SCHEMATIC Well #A-2 Completed: 12/5/2014 RKB to TBG Hngr=36.40' CASING DETAIL SIZE WTGRADE CONN ID TOP BTM. 1 II 2 13-3/8" 61 K-55 Butt 12.515 Surf. 1,023' '•4 3 9-5/8" 40&43.5 K-55&N-80 8rd LT&C 8.755 Surf 6,546' MN4 TUBING DETAIL 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf 6,094' L JEWELRY DETAIL NO. Depth ID Item 42' TBG Hanger 1 295' 2.310 SSSV-2-7/8"Flowsafe,BTE-5TR 2 319' 2.954 9-5/8"Dual String Hydroset Packer 3 338' 2.310 X-Nipple 4 352' 2.441 GLM 5 5,982' -- Discharge,Bolt-On 6 5,984' -- Pump(45 Stg SF1750) &(2)125 Stg SF1750 7 6,042' -- Seals I 8 6,059' -- Motor 456 Series,FMP1,180 HP,2610,47 A _- CZN 47-5 9 6,094' -- Centrilizer/Anode = CZN 48-5 1 - CZN 50-0 - CZN 50-3 = CZN 50-6 CZN 51-0 CZN 51-6 Perforation Details Cx Top Btm Top Btm Fa DZN 53-0 Amount Condition Zone (MD) (MD) (TVD) (TVD) Q DZN53-8 CZN 47-5 4,738' 4,767' 4,566' 4,594' 29' Open i = CZN 48-5 4,833' 4,839' 4,658' 4,664' 6' Open DZN 545 = DZN 54-9 CZN 50-0 4,996' 5,010' 4,816' 4,829' 14' Open CZN 50-3 5,022' 5,048' 4,841' 4,866' 26' Open DZN 55-7 l la CZN 50-6 5,088' 5,100' 4,905' 4,917' 12' Open - DZN56-1 CZN 51-0 5,132' 5,142' 4,948' 4,958' 10' Open CZN 51-6 5,161' 5,223' 4,976' 5,037' 62' Open 5,288' 5,290' 5,100' 5,102' 2' Sqz Perfs - DZN 57-2 DZN 53-0 5,298' 5,328' 5,110' 5,139' 30' Open = DZN 53-0 5,360' 5,379' 5,170' 5,189' 19' Open ` DZN 53-8 5,386' 5,434' 5,196' 5,242' 48' Open il - DZN 53-8 5,400' 5,410' 5,209' 5,219' 10' Cmt sqz'd off gas EZN 58-1 DZN 53-8 5,410' 5,430' 5,219' 5,239' 20' Reperfd Open f/Prod i DZN 54-5 5,450' 5,480' 5,258' 5,287' 30' Reperf'd Open f/Prod EZN 58-7 DZN 54-5 5,457' 5,478' 5,265' 5,285' 21' Open 5 DZN 54-9 5,494' 5,538' 5,301' 5,344' 44' Open 1111 6 _EZN 60-0 DZN 54-9 5,500' 5,532' 5,307' 5,338' 32' Reperf'd Open f/Prod _ 7 - DZN 55-7 5,562' 5,594' 5,367' 5,398' 32' Open 5,590' 5,592' 5,395' 5,397' 2' Sqz Perfs 8 CP DZN 56-1 5,611' 5,698' 5,415' 5,500' 87' Open `11_ 1' 9 DZN 56-1 5,630' 5,640' 5,434' 5,443' 10' Reperfd Open f/Prod DZN 56-1 5,660' 5,693' 5,463' 5,495' 33' Reperfd Open f/Prod = DZN 57-2 5,728' 5,792' 5,529' 5,592' 64' Open DZN 57-2 5,730' 5,785' 5,531' 5,585' 55' Reperfd Open f/Prod - Hemlock EZN 58-1 5,816' 5,858' 5,615' 5,656' 42' Open - EZN 58-1 5,820' 5,825' 5,619' 5,624' 5' Cmt sqz'd off gas = EZN 58-1 5,825' 5,850' 5,624' 5,648' 25' Open f/Prod EZN 58-7 5,872' 5,964' 5,670' 5,760' 92' Open EZN 58-7 5,900' 5,960' 5,697' 5,756' 60' Open f/Prod EZN 60-0 5,986' 6,007' 5,781' 5,802' 21' Open EZN 60-0 5,990' 6,020' 5,785' 5,814' 30' Open f/Prod KB ELEV=101' Hemlock 6,090' 6,092' 5,883' 5,885' 2' Sqz Perfs PBTD=6,461' Hemlock 6,110' 6,140' 5,903' 5,932' 30' Open f/Prod Hemlock 6,110' 6,420' 5,903' 6,209' 310' Open ANGLE thru INTERVAL=12.7° 6,149' 6,150' 5,941' 5,942' 1' Erroneously perfd Hemlock 6,150' 6,285' 5,942' 6,075' 135' Open f/Prod Hemlock 6,300' 6,420' 6,090' 6,209' 120' Open f/Prod Updated by: 1LL 1/6/2015 Trading Bay Unit PROPOSED Well#A-2 Completed: FUTURE RKB to TBG Hngr=36.40' CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 2 13-3/8" 61 K-55 Butt 12.515 Surf. 1,023' 9-5/8" 40&43.5 K-55&N-80 8rd LT&C 8.755 Surf 6,546' TUBING DETAIL 3-1/2" 9.2 L-80 Supermax 2.992 Surf ±6,000 L 3 JEWELRY DETAIL NO. Depth ID Item 42' TBG Hanger 1 ±300' SSSV 2 ±350' Packer w/Vent valve 4 - 3 ±2,186' GLM 4 ±3,581' GLM 5 ±4,461' GLM 6 ±4,471' X-Nipple 5 X 6 7 ±6,100' Bottom of ESP CZN 47-5 CZN48-5 Perforation Details - CZN 50-0 Top Btm Top Btm CZN Zone (MD) (MD) (TVD) (TVD) Amount Condition CZN 50-6 CZN 47-5 4,738' 4,767' 4,566' 4,594' 29' Open CZN 51-0 CZN 48-5 4,833' 4,839' 4,658' 4,664' 6' Open CZN 51-6 CZN 50-0 4,996' 5,010' 4,816' 4,829' 14' Open 1a CZN 50-3 5,022' 5,048' 4,841' 4,866' 26' Open s DZN 53-0 CZN 50-6 5,088' 5,100' 4,905' 4,917' 12' Open CZN 51-0 5,132' 5,142' 4,948' 4,958' 10' Open DZN538 CZN 51-6 5,161' 5,223' 4,976' 5,037' 62' Open DZN 54-5 5,288' 5,290' 5,100' 5,102' 2' Sqz Perfs = DZN 54-9 DZN 53-0 5,298' 5,328' 5,110' 5,139' 30' Open • M DZN 55-7 DZN 53-0 5,360' 5,379' 5,170' 5,189' 19' Open LE DZN56-1 DZN 53-8 5,386' 5,434' 5,196' 5,242' 48' Open DZN 53-8 5,400' 5,410' 5,209' 5,219' 10' Cmt sqz'd off gas DZN 53-8 5,410' 5,430' 5,219' 5,239' 20' Reperfd Open f/Prod DZN 57-2 DZN 54-5 5,450' 5,480' 5,258' 5,287' 30' Reperf'd Open f/Prod M DZN 54-5 5,457' 5,478' 5,265' 5,285' 21' Open DZN 54-9 5,494' 5,538' 5,301' 5,344' 44' Open g DZN 54-9 5,500' 5,532' 5,307' 5,338' 32' Reperfd Open f/Prod EZN 58-1 DZN 55-7 5,562' 5,594' 5,367' 5,398' 32' Open 5,590' 5,592' 5,395' 5,397' 2' Sqz Perfs -EZN 58-7 DZN 56-1 5,611' 5,698' 5,415' 5,500' 87' Open Cr. DZN 56-1 5,630' 5,640' 5,434' 5,443' 10' Reperfd Open f/Prod - - - DZN 56-1 5,660' 5,693' 5,463' 5,495' 33' Reperfd Open f/Prod EZN 60-0 DZN 57-2 5,728' 5,792' 5,529' 5,592' 64' Open DZN 57-2 5,730' 5,785' 5,531' 5,585' 55' Reperfd Open f/Prod EZN 58-1 5,816' 5,858' 5,615' 5,656' 42' Open EZN 58-1 5,820' 5,825' 5,619' 5,624' 5' Cmt sqi d off gas - 7 EZN 58-1 5,825' 5,850' 5,624' 5,648' 25' Open f/Prod EZN 58-7 5,872' 5,964' 5,670' 5,760' 92' Open EZN 58-7 5,900' 5,960' 5,697' 5,756' 60' Open f/Prod Hemlock EZN 60-0 5,986' 6,007' 5,781' 5,802' 21' Open - EZN 60-0 5,990' 6,020' 5,785' 5,814' 30' Open f/Prod _ Hemlock 6,090' 6,092' 5,883' 5,885' 2' Sqz Perfs Hemlock 6,110' 6,140' 5,903' 5,932' 30' Open f/Prod Hemlock 6,110' 6,420' 5,903' 6,209' 310' Open 6,149' 6,150' 5,941' 5,942' 1' Erroneously perfd Hemlock 6,150' 6,285' 5,942' 6,075' 135' Open f/Prod / \ Hemlock 6,300' 6,420' 6,090' 6,209' 120' Open f/Prod KB ELEV=101' PBTD=6,461' ANGLE thru INTERVAL=12.7° Updated by: JLL 02/11/15 Monopod Platform A-2 Current ESP 12/08/2014 Hilenrp ‘I:e.l.n.1.1( Monopod Platform Tubing hanger,CIW-DCB-ESP, A-2 11 X 3 X EUE lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 3"type H BPV profile,5''A EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union I ni / ui NINO .�^ . Valve,swab,WKM-M, Q 3 1/8 5M FE,HWO, Mn(p M T-24 e'-6-0 0 .._O�.. Valve,WKM-M,3 1/8 5M FE,w/ iMA-16 operator Valve,wing,WKM-M, ' o 2 1/16 5M FE,HWO, tv o! - T- 24 ei Valve,lower master,WKM-M, P r_ 0.4 31/85MFE,HWO,T-24 + OQ Adapter,CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE,prepped for _ 5 1/<ESP neck,2-'/2 npt continuous 1 I control line ports Tubing head,CIW-DCB, � -— 13 5/8 3M X 11 5M,w/ c.LN i�I_ 2-2 1/16 5M SSO, _ X bottom I , I I Valve,WKM-M,2 1/16 5M FE, Replaced tubing head '+ HWO,DD 2014 i1 Ill' �� ptip 1 �I 000 �I 1 II, i,i la 1 Casing head, Shaffer KD, • 13 / w 13 3/8 SOW,w/2 2" III Jim I 2"LP CIW ball valve € .rS le immi,r Monopod Platform 2013 BOP Stack Hife,rp Moan.ILIA. 03/12/2013 Rig Floor Bottom of air boot flange 5'below rig floor 16" 14.72' 9.50' Pipe 111'111 111 111111 0 0 fffil n fel ftL 3.74' Shaffer {135/85M ff1f )111 Mlitt ttt 26.25' I Shaffer LXT — © 2 7/8-5 Variables 2.50' y 13 5/8 5M Blind • 1.76 ' -; - - ; . _ 'll°,13580Cross • • 5M FE FE Ili I 11111111 w/3 1/8 5M EFO --_ w/2 1/16 5M Choke and Kill valves w/Unbolt end connections for lines Ili 1.!1 II' ill 2.83' '.'111411111111 Dual Cameron Flex rams 1114 I 11111 .70' 4011 14.20" Drill deck UOCD 1911 Riser 14.20' 1 135/85M FE X135/85M FE I I II I IIhIII Ei LUAU 1.1 III Spacer spool 1S' 13 5/8 5M FEX 11 3M I lit 11t iii Ill Wellhead @ 15.00' • STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM, .ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Repair Well❑ Plug Perforations ❑ Perforate 0 Other El Install ESP Performed: Alter Casing❑ Pull Tubing 0 Stimulate-Frac ❑ Waiver El Time Extension El Change Approved Program El Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Name: Development 0 Exploratory❑ 166-049 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,Alaska 99503 50-733-10056-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Trading Bay Field/Middle Kenai C,Middle Kenai D and E&Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 6,669 feet Plugs measured N/A t E C IVE D true vertical 6,448 feet Junk measured N/A feet JAN 0 6 2015 Effective Depth measured 6,461 feet Packer measured 319 feet true vertical 6,236 feet true vertical 319 feet AC)GCO Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,023' 13-3/8" 1,023' 1,007' 3,090 psi 1,540 psi Intermediate Production 6,546' 9-5/8" 6,546' 6,335' 3,950 psi 2,570 psi Liner b) 1` 4 SCANNED ,. Perforation depth Measured depth See Attached Schematic : \ 1 c LL1,> True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80 6,094'(MD) 5,887'(ND) Packers and SSSV(type,measured and true vertical depth) Hyd.Pkr 319'(MD)319'(TVD) BTE-5TR SSSV 295'(MD)295'(ND) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 78 1021 462 520 100 Subsequent to operation: 71 49 1196 220 160 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Service❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil El Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ 3USP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-573 Contact Ted Kramer Email tkramer( hilcorq.com Printed Name Ted kramer Title Sr.Operations Engineer Signature "<.Z/__ . Phone 907-777-8420 Date 1/6/20 1 ABC X195 JAN - 8 Ms Form 10-404 Revised 10/2012 /,, cor ,e*./,--- Submit Original Only • Trading Bay Unit e u SCHEMATIC Well #A-2 Completed: 12/5/2014 RKB to TBG Hngr=36.40' CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 'dao 11,1 2 13-3/8" 61 K-55 Butt 12.515 Surf. 1,023' ere 3 9-5/8" 40&43.5 K-55&N-80 8rd LT&C 8.755 Surf 6,546' • 4 TUBING DETAIL 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf 6,094' L JEWELRY DETAIL NO. Depth ID Item 42' TBG Hanger 1 295' 2.310 SSSV-2-7/8"Flowsafe,BTE-5TR 2 319' 2.954 9-5/8"Dual String Hydroset Packer 3 338' 2.310 X-Nipple 4 352' 2.441 GLM 5 5,982' -- Discharge,Bolt-On 6 5,984' -- Pump(45 Stg SF1750) &(2)125 Stg 511750 7 6,042' -- Seals 8 6,059' -- Motor 456 Series,FMP1,180 HP,2610,47 A CZN 47-5 9 6,094' -- Centrilizer/Anode = CZN 48-5 CZN 50-0 - CZN 50-3 = CZN 50-6 i s CZN 51-0 CZN 51-6 Perforation Details r: Top Btm Top Btm s DZN 530 Zone (MD) (MD) (TVD) (TVD) Amount Condition ra - DZN53-8 CZN 47-5 4,738' 4,767' 4,566' 4,594' 29' Open DZN 545 CZN 48-5 4,833' 4,839' 4,658' 4,664' 6' Open = CZN 50-0 4,996' 5,010' 4,816' 4,829' 14' Open DZN 54-9 CZN 50-3 5,022' 5,048' 4,841' 4,866' 26' Open - DZN 55-7 CZN 50-6 5,088' 5,100' 4,905' 4,917' 12' Open DZN56-1 CZN 51-0 5,132' 5,142' 4,948' 4,958' 10' Open CZN 51-6 5,161' 5,223' 4,976' 5,037' 62' Open 5,288' 5,290' 5,100' 5,102' 2' Sqz Perfs DZN 57-2 DZN 53-0 5,298' 5,328' 5,110' 5,139' 30' Open DZN 53-0 5,360' 5,379' 5,170' 5,189' 19' Open s DZN 53-8 5,386' 5,434' 5,196' 5,242' 48' Open ia € - DZN 53-8 5,400' 5,410' 5,209' 5,219' 10' Cmt sqz'd off gas =EZN 58-1 DZN 53-8 5,410' 5,430' 5,219' 5,239' 20' Reperf'd Open f/Prod DZN 54-5 5,450' 5,480' 5,258' 5,287' 30' Reperf'd Open f/Prod EZN 58-7 DZN 54-5 5,457' 5,478' 5,265' 5,285' 21' Open 5 DZN 54-9 5,494' 5,538' 5,301' 5,344' 44' Open 6 -EZN 60-0 DZN 54-9 5,500' 5,532' 5,307' 5,338' 32' Reperf'd Open f/Prod 7 DZN 55-7 5,562' 5,594' 5,367' 5,398' 32' Open 5,590' 5,592' 5,395' 5,397' 2' Sqz Perfs 8 Cx DZN 56-1 5,611' 5,698' 5,415' 5,500' 87' Open 9 DZN 56-1 5,630' 5,640' 5,434' 5,443' 10' Reperf'd Open f/Prod DZN 56-1 5,660' 5,693' 5,463' 5,495' 33' Reperf'd Open f/Prod DZN 57-2 5,728' 5,792' 5,529' 5,592' 64' Open DZN 57-2 5,730' 5,785' 5,531' 5,585' 55' Reperf'd Open f/Prod - Hemlock EZN 58-1 5,816' 5,858' 5,615' 5,656' 42' Open EZN 58-1 5,820' 5,825' 5,619' 5,624' 5' Cmt sqz'd off gas = EZN 58-1 5,825' 5,850' 5,624' 5,648' 25' Open f/Prod EZN 58-7 5,872' 5,964' 5,670' 5,760' 92' Open EZN 58-7 5,900' 5,960' 5,697' 5,756' 60' Open f/Prod EZN 60-0 5,986' 6,007' 5,781' 5,802' 21' Open EZN 60-0 5,990' 6,020' 5,785' 5,814' 30' Open f/Prod KB ELEV=101' Hemlock 6,090' 6,092' 5,883' 5,885' 2' Sqz Perfs PBTD=6,461' Hemlock 6,110' 6,140' 5,903' 5,932' 30' Open f/Prod Hemlock 6,110' 6,420' 5,903' 6,209' 310' Open ANGLE thru INTERVAL=12.7° 6,149' 6,150' 5,941' 5,942' 1' Erroneously perf'd Hemlock 6,150' 6,285' 5,942' 6,075' 135' Open f/Prod Hemlock 6,300' 6,420' 6,090' 6,209' 120' Open f/Prod Updated by: JLL 1/6/2015 Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/03/14- Monday Nipple up BOPs. Had to nipple up double gate so we could run the dual flex rams. Function test BOPE. Rig up Weatherford equipment. Make up test joints for dual string test. Make up test hoses. Fill stack and choke manifold. Shell test low 250 psi good. High test had leak on flange between double gate and mud cross. Re-torque bolts on mud cross. Also, re-torque bolts on annular preventer. Annulus pressure at 60 psi. Bleeding off to production. After re-torqueing flange below double gate, still had leak. Lay down test joints. Pull flow nipple. Break and pick up double gate. Change out API ring gasket. Lost 1560 bbls 8.6 ppg 3% KCL and 200 bbls sized salt pill total. 11/04/14-Tuesday Change out API ring gasket below double gate. Nipple up flow nipple and secure stack. Ann had been pressuring up and the strings were starting to have a slight bleed through the BPVs. It had been more than 24 hrs since we set the valves so we decided to fill the tbg. RU on LS. Had 300 psi on tbg and 65 on ann. Pumped 50 bbls. Tbg press 0 psi and ann 84 psi gas. Open to production header. RU on SS and pump 130 bbls KCL. Still no pressure on tbg and still getting gas f/ann. Shut dn. RU test jts. Attempt to get test but pressure still bleeding off with no visible leaks. Bleed off and open rams. Tighten test jts into hanger. Test BOPs with dual string rams. Test all equip 250L/2500H except for Annular, Blinds, and 2 7/8 floor valve. Witness of test waived by Jim Regg, AOGCC. RU to pump down short string. Pump 40 bbls SS pill and 50 bbls KCL at 2 BPM. 0 psi on tbg and 85 psi gas pressure on ann. Switch to LS. Pump 40 bbls SS pill and chase w/ KCL. At 62 bbls we started to get tbg pressure and at 77 bbls we started to get crude oil back from ann. Pump another 140 bbls and we started getting water and crude mixed. Pump 8 more bbls and shut down. Swap back to short string pump @ 2 bbls/min with 50 psi taking 20 bbls to fill pipe. Pressure increased to 120 psi. Increase pump rate to 2.5 bbls/min with pump pressure increasing to 220 psi, pumping 105 bbls total. Pull BPV on long side and install 2 way check. Test BOPS. Test annular w/3 1/2" 250/2500 psi 5 min swap test jt to 2 7/8" test same with TIW valve installed. Pull BPV on short side and install TWC.Test blinds 250/2500 psi 5 min. Pull TWCs & install BPVs Well on slight vac. R/D test equip. Blow down choke and T.D. R/U to pump down S.S. pump KCL @ 2 bpm with 50 psi increase rate T/2.5 bpm with P.P. increasing to 70 psi @ 65 bbls pumped. Pump pressure increased to 180 psi. At 85 bbls, pumped oil to surface at annulus. At 105 bbls switched to 40 bbl SSP returns cleaned up @ 115 bbls away. Chased pill with 10 bbls KCL to clear surface lines.Total pumped = 155 bbls. With pump off ANN pressure fell from 90 psi to "0" in 5 min. Pick up 3rd party tools to rig floor. R/U long bails & dual elevators. R/U to pump down LS. Pump KCL @ 2.5 bbls/min with 50 psi P.P. 47 bbls away caught pressure 80 psi. Had returns at 68 bbls pumped W/200psi P.P. and 85 psi on annulus. Slowed pump to 2 bbl/min. 90 bbls total pumped. Returns clean. Ann psi bled F/85 psi T/ "0" in 5 min and on slight vac. R/U on short side spot 40 bbl SSP in tubing chase W/10 bbl 8.6 ppg 3% KCL to clear surface lines. M/U TIW valves on both strings. Pull hanger free with 145K P/U wt. Monitor well, losses @ 60 bbl/ hr. Pull hanger to floor W/110K up wt. Rig up dual spider. Break off and set landing jts in mouse hole to remove TIW valves & pup joints. Lost 2333 bbls 8.6 ppg 3% KCL and 360 bbls sized salt pill total. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/05/14-Wednesday Both tbg strings had pressure. RU on SS and pump tbg vol plus 10 bbls. Swap over to long string and circ one full circ. Highest gas units 425. Hole taking 30 BPH. Monitor well. Lay dn circ equip. Break out and lay down hangers. POOH laying down 3 1/2 IBT dual string tbg to SSSVs at 320'. Hole taking 45 BPH. Change slips and elevators over to 2 7/8 on the LS side. RU another set of power tongs for the 2 7/8. Continue POOH laying down 2 7/8 IBT and 3 1/2 IBT dual string. [at 1400 hrs hole taking 48 BPH]. Loss rate has been increasing so we decided to spot another 40 bbl SS pill before we got too far from the top of the packer. Had a valve drill and while we had our valves in we pumped 40 bbls SS pill and chased it with 20 bbls KCL. RD circ equip. Continue POOH F/4,894'T/3,800' laying dn 2 7/8 IBT and 3 1/2 IBT dual string. [Loss rate at 1600 hrs = 56.3 BPH][Loss rate at 1700 hrs= 27 BPH]. Continue T/ POOH F/3,800'T/ 1,784' laying dn 2 7/8 IBT and 3 1/2 IBT dual string [losses increased to 50 bbls/hr @ 23:00 hrs]. R/U and pump 30 bbl SSP chase with 10 bbl 3% KCL to clear lines while cleaning/power washing rig floor. Continue T/ POOH F/ 1,784'T/ 1,691' laying dn 2 7/8 IBT and 3 1/2 IBT dual string tubing. POOH F/ 1,691' T/400' laying dn 2 7/8 IBT and 3 1/2 IBT dual string tubing. [losses @ report time = 48 bbls/hr]. Lost 3005 bbls 8.6 ppg 3% KCL and 400 bbls sized salt pill total. 11/06/14-Thursday POOH laying dn 2 7/8 IBT&3 1/2 IBT dual string. [Hole taking 26 BPH at 0700 hrs.] Recovery of all tubulars to the tbg cuts. RD equip. Clean floor, handrails, slide, and deck. [Loss rate at 1330 hrs was 54 BPH.] Clean off stack. Change upper rams to 5". Change out TD saver sub f/3 1/2 IF t/4 1/2 IF. Put new guide on for 5" DP. [Loss rate at 1500 hrs was 33 BPH] Install Tesco bails. M/U test joint. R/U trip tank to annulus. Fill stack. Test Bops. Set test plug W/5" test joint. Started testing the 2500 psi high test. The annular started to leak. Bleed off pressure and function the bag. Started testing again. Annular was holding but two lock downs started to leak. Bleed down and tighten packing glands. Started again,this time started leaking by the test plug. Pull to floor. C/O "0" rings on next test. Continued to leak. Pull to rig floor & remove. Wrap grove with Teflon tape to raise "0" ring. Also applied grease to outside of"0" ring to help seal it.This time got the annular, floor valves and upper 5" rams top to test. On the lower VBR rams W/the 5" high test, it flat lined for the first 2 min then fell and started leaking by the test plug again. Pulled it back to the floor. Applied more Teflon to the "0" ring grove and grease on the "0" ring. Leaking by test plug. R/D test equipment. Move 2 stands of tbg to drillers side. Prep to pick up and stand back 5" drill pipe in derrick. [Have replacement test plug coming out]. Lost 3850 bbls 8.6 ppg 3% KCL and 431 bbls sized salt pill total. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/07/14- Friday PU 6 1/2 DCs and 5" DP and stand it back in the derrick. [Loss rate at 1100 hrs was 40 BPH]. PU 2 7/8 test jt and set test plug. Test 2 7/8 on lower rams to 250 low and 2500 psi high. Pull 2 7/8 test jt and MU 5" test jt.Test Annular, upper rams, and lower rams to 250 low and 2500 psi high. Leave test jt in and let control tech hand work on BOP control touch screen settings. RD test jt and set wear ring. Get fishing tools to rig floor. PU fishing BHA#1. 8 1/8 bowen overshot w/ extension, [dressed w/a 2 7/8 grapple], Dbl pin sub, bit sub, bumper sub, oil jars, XO, 3 -6 5/8 DCs, XO, and Acc jars= 138.24'. RIH with 10 stds of 5" DP out of derrick to 1,085', and continue RIH picking up DP T/5,161'. Kelly up. Wash down at 5bbl/min with 100 psi SPP F/5,161'T/tag @ 5,192' up wt= 153K dn wt= 126K, set dn 10K with 5K over pull. Slack off to 12K at 5,206' W/5K over pull. Rotate onto fish @ 5 rpm, 6K torque. Pick up appears to be slipping off of fish. Attempted to latch onto fish setting down 20K, 25K, and 30K pumps and rotation on and off. Decision made to pooh. POOH F/5,206'T/surface. Recovered 13.71' 2 7/8" Fish. Lay down fish. Break overshot to check grapple, reinstall. Run# 2, Make back up fishing BHA and RIH T/2,000' @ report time. Lost 4829 bbls 8.6 ppg 3% KCL and 431 bbls sized salt pill total. 11/08/14-Saturday RIH w/overshot to 5,190'. Fill pipe. Engage fish on LS at 5,208'.Attempt to straight pull working up to 95k overpull. Cock jars and set them off 4 times w/the last time jarring at 70k over. Fish pulled free w/a 6k increase in up wt. PU to 5,190'. Circ bottoms up watching for gas. No extra gas on bottoms up. Spot 35 bbl SS pill as a balanced plug on bottom. POOH to BHA. Work BHA. Recovered 4.35 2 7/8 tbg.This puts the top of the LS at 5,212.50' and the top of the short string at 5,211.79' = .71 difference. Not enough to grab one string with out a short catch grapple or a smaller shoe. Service rig and topdrive while lining up tools. Also working on installing solenoid in BOP panel at accumulator to regulate pressure adjustment on annular. Adjust kelly hose. Clean screens on mud pumps. Fishing tools arrived on platform. Strap and PU fishing BHA#3 -4 11/16" short catch overshot w/3 1/2 grapple, XO, 1 jt 3 1/2 DP, XO, Dbl pin sub, bit sub, bumper sub, oil jars,, XO, 3 DCs, XO, acc jars, =166.26'. RIH W/ BHA @ 166'T/5,189'. Kelly up, break circ-5 bbl/min. W/40 psi SPP. up wt= 160K, dn wt = 134K, rot. wt= 145K. RIH to tag at 5,208'. Tag twice P/U clean. Est. Rotation. Rotate at 5 RPM to 5,210' engage fish. Set dn. 30K then P/U 10K over Rot wt. to set grapple. Release safety sub with 10 turns to the right. POOH F/5,210'T/ BHA @ 166'. Stand back collars. L/D Fish. Length = 10.90'. P/U fishing BHA#4= 8 1/8 bowen overshot w/extension, [dressed w/a 2 7/8 grapple], Dbl pin sub, bit sub, bumper sub, oil jars, XO, 3 -6 5/8 DCs, XO, and Acc jars. = 138.24'. Run in hole W/fishing BHA#4 T/5,140'. Kelly up, break circ. Pumping @ 5 bbl/min with 100 psi SPP, up wt =153K dn =126K. See TOF @ 5,211' & no go @ 5,217'. Set down 20K Straight pull 250K&Jar at 230K Jar 5 licks to free fish. Up wt=163K [+10K I. Pooh to position tool jt at rotary. Circ- surface T/surface @ 7 bbl/min W/210 psi SPP. max gas units @ btms up 155 units. Pump 40 bbl SS Pill and chase with 75 BBL 3% KCL to use as a balanced plug. Monitor well. Start POOH @ 06:00 hrs. Lost 5596 bbls 8.6 ppg 3% KCL and 466 bbls sized salt pill total. Avg losses to well 24 hrs = 34 bbls/hr. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/09/14-Sunday POOH slow with packer to BHA. RU and lay dn fish. Recovered 10' stub on top of packer on LS side. Recovered packer and 18.59 below packer on LS side. Recovered 298' of tbg below pkr on SS side. Tbg on SS side is rotten w/holes all over. {Hole taking 27 BPH}. Clean up floor. Have Control Tech work on accumulator while cleaning. PU overshot and break tbg, cut jt out. PU Fishing BHA#5. 8 1/8 bowen overshot w/extension and 2 7/8 grapple, dbl pin sub, bit sub, bumper sub, oil jars, XO, 3 DCs, XO, acc jars, = 138.24 [Hole taking 15 BPH]. RIH to top of LS stub. Break circ and wash down to 5,256'. Started taking wt and fell through. Chase down hole to 5,372'. Set dn 30k. PU and it had 10k overpull for 15'then fell off. [It looked like we went over the top of the LS and as soon as it took a little wt the pipe collapsed below at a unknown depth]. POOH F/5,340'T/ BHA @ 138'. Work BHA. L/D 2 7/8" Fish - Length = 227.26'. M/U BHA#6, 8 1/8" Bowen overshot W/ hollow mill container& 2 7/8" hollow mill, XO Bushing, [1]jt 8 1/8" Washpipe,Top sub, Double pin sub, Bit sub W/float, 6 1/4" Bowen lub. bumper sub, 6 1/4" Bowen oil jar, XO sub, [3] Drill collars, XO sub, 6 1/4" Bowen ACC jar. BHA Length = 166.93'. RIH WI [1] std 5" D.P. Secure well. RIH W/4 stds 5" D.P. T/635' hang blocks, slip &cut 80' drilling line. Adjust drawworks break. Service rig. @ Report time started running in hole F/635'. Lost 6190 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs= 26.5 bbls/hr. 11/10/14- Monday RIH to 5,471'. Fill pipe and break circ. Engage top of fish at 5,473'. Rotate and work dn over fish to 5,489'. PU with a 5k increase in string wt. Make a couple attempts to go back down but we sat down at 5,489'. PU to 5,471'. Blow dn TD and mud lines. POOH to BHA. Break down overshot and remove two pieces of rotten twisted off 2 7/8 tbg. Total =2.70'. Rig up ST-80 and test same. Had to tighten a couple lines and hook up the line to the torque gauge. MU BHA#7, 7 1/2 X 5" box tap, 1 jt 8 1/8 washpipe, top sub, dbl pin sub, bit sub, bumper sub, oil jars, XO, 3 DCs, XO, acc jars. = 162.21. RIH to 5,469' fill pipe and get parameters. Wash down to top of fish at 5,489'. Work down rotating until TD stalled. PU and pull 10k over and wt fell off. Make several attempts to get a bite on the fish, but couldn't get it to hold on. Work down to 5,495'. Blow down TD and POOH F/5,495' BHA@ 162'. Work BHA, Fish = 32 Lbs Iron. M/U BHA#8, 8 1/2" x 6" MM Shoe, [3]jts 8 1/8" Washpipe, Top sub, Double pin sub, [4] Boot baskets, Bit Sub W/ Float, 6 1/4" Bowen Lub. Bumper sub, 6 1/4" Oil jar, XO Sub, [3] 6 5/8" Drill collars, XO Sub, 6 1/4" Bowen ACC Jar. RIH F/245'T/5,448' Kelly up. Break circ. Wash F/5,448'T/Tag @ 5,494' UP wt = 165K, Dn wt = 135K, Rot wt = 145K Tq off= 8/9K, Rot @ 60 RPM, pumping @ 7/10 BBL/ MIN. & 140/220 SPP. Work over fish and dress W/8 to 12K Dn wt. Mill and work over fish T/5,529' saw top of S.S. @ 5,519'. Attempt to free fish. Observed additional 5/10K up wt with no additional progress down. Decision made T/ POOH. POOH F/5,529'. Lost 6406 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs = 9 bbls/hr @ Report time losses = "0" bbls/hr. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/11/14-Tuesday POOH with 8.5" X 6" mill shoe, washpipe, and boot baskets. Break down BHA. Lay down boot baskets. PU and break mill shoe off washpipe. Shoe and washpipe are full of tbg. Clean/clear rig floor. Clean junk bsk. Recovered 106.5# Iron debris. Remove tbg from wash pipe. Recovered 83#junk iron & 14' of 2-7/8" Tbg. Est T.O.F @ 5,529'. Pull wear ring and m/up test jt. Unable to get test plug to hold. Pull same chg/out 0-ring and reset.Test Bope 250-2500 psi as per AOGCC regulations. Witness of test waived by Mr.Jim Regg, AOGCC. Rig dn test equipment (monitor well on trip tank via annulus valve w/avg loss rate @ 6 bph). R/D test equipment, pull test plug & install wear bushing. M/U BHA#9, 8 1/2"x6" MM Shoe, [3]jts 8 1/8" washpipe,Top Sub, Double Pin Sub, [4] Boot Baskets, Bit Sub W/ Float, 6 1/4" Bowen Lub. Bumper Sub, 6 1/4" Bowen Oil Jar,XO Sub, [3] 6 5/8" Drill Collars, X0 Sub, 6 1/4" ACC Jar,Total BHA Length = 251.29'. RIH W/ DP F/251'T/3,000'. Circ, fill pipe, cont. in hole T/5,464'. Kelly up & Break circ. RIH T/Tag @ 5,529' up wt= 165K, dn wt = 135K, rot. wt = 145K, pump @ 5bbl/min W/ 115 SPP. @ 60 rpm, W/6 to7K tq off btm. Dress fish and mill T/5,572' at report time with 5T/10K over dn wt. Lost 6610 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs = 8.5 bbls/hr.J-bsk recovery Daily= 106.5#Total = 106.5#. Ditch magnets Daily= 35#Total =35# . Scrap iron out of WP Non intact Tbg or blast Jt Daily= 83#total =115# . Tbg/ Blast jt intact Daily= 14.00' Total = 600'. 11/12/14-Wednesday Continue washing over fish f/5,572't/5,584'w/occasional stalls. P/up w/+/- 6' travel, fired jars+50K over X3 to free wash pipe. Circ Btm up @ 8 bpm @140 psi (losses went from 14 bph to 2 bph). Attempt pooh (no-go) had to pump ooh, firing jar both ways for+/-180'. Dn pump continue working ooh w/ up to 85k over pulls and dn jar to free for total of+/- 300' (5,270') then started pull w/ normal up weight. Monitor static well w/4 bph loss rate. Continue pooh on elevators to chk tools. L/dn, chk and clean BHA. Recovered 119.0#in Junk bsk, 75.90' 2-7/8" tbg, 15#scrap iron & 36#off ditch magnets. Service rig. P/up m/up BHA#10 added string magnet and 3 more 6-5/8" dc'c, BHA= 352.8'.Test accumulator control w/new 1/2" dump line. RIH fill pipe @ +/-3,000' continue T/ RIH T/5,565'. P/U single & Kelly up. Break circ. Tag up @ 5,582' up wt= 175K, dn wt = 140K, RT= 157K, Rotate @ 60 rpm SPP = 160 psi pumping @ 5 bbm, with 6k to/8K Tq off btm 8/13K on. Mill over fish F/5,582'T/5,594' w/same parameters&8K to 13K torque. Circ- btms up @ 13 bbls/ min 1050 psi. Stack 30K dn wt. pumps& rotation off. P/U clean. POOH F/5,594'T/ BHA @353'. Losses while POOH = 6 BBL/HR. Work, L/dn BHA#10. Recovered 100 lbs Iron F/Junk baskets, 36 lbs F/String Magnet & 1 lb F/ Ditch magnets. Clean &organize rig floor. M/U BHA# 11 -8 1/8" Bowen Overshot, X0 Bushing, [1]jt 8 1/8" Washpipe,Top Sub, Double Pin Sub, Bit Sub W/float, 6 1/4" Bowen Lub Bumper Sub, 6 1/4" Bowen Oil Jar, X0 Sub, [6] 6 5/8" Drill collars XO Sub 6 1/4" Bowen Oil Jar. BHA= 261.01'. Service Rig. At report time running in hole W/ DP F/ BHA. Lost 6717 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs=4.5 bbls/hr.J-bsk recovery Daily= 219 #Total = 325.5#. Ditch & String magnets Daily= 74#Total =109#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 15#total =130#. Tbg/ Blast jt intact Daily= 75.9' Total = 675.9'. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/13/14-Thursday Continue RIH w/ BHA#11 (0/S loaded w/5-3/4" grapple) f/261' t/5,568'. Kelly up and brk circ. Establish parameters, tag and engage fish @ 5,594' (work tools seen slight indication of swallow and slight 2k over pull, unable set grapple). Pooh to BHA. Work and chk BHA (had couple large gouges on face of cut lip guide and indication of swallow past grapple). Monitor static well (4 bph loss rate). Power wash/clean rig floor. Service rig. M/up BHA#12 - MM shoe 8-1/2" x 7", 1-jt 8-1/8" wp, top sub, dlb pin, (4) 7"j-bsk, Bit sub w/float, string magnet, 6-1/4" BS, OJ (6) 6-5/8" dc's, Acc jar= 290.01'. RIH fill pipe +/- 3,000'. Kelly up. Brk circ and establish parameters, up wt. = 170K, dn wt = 140K, rt wt= 155K, pumping @ 5 bbl/min W/ 130 psi. Increasing to 16 bbl/min WI 1200 psi, rotating @ 60 rpm WI 8K tq off& 15K.Tag TOF @ 5,594'. Dress TOF F/5,594' T/5,603' with 2/5K over rotating wt. POOH F/5,603' T/ BHA @ 290'. Work/ lay dn BHA#12. Recover 30 lbs iron F/junk baskets & 29 lbs F/string magnet. Losses on trip OOH = 2.5 bbl/hr. Clear/clean rig floor. Service rig. M/U BHA#13 -8 1/8" Bowen Overshot, XO Bushing, [1]jt 8 1/8" Washpipe,Top Sub, Double Pin Sub, Bit Sub W/ Float, 6 1/4" Bowen Lub. Bumper Sub, 6 1/4" Bowen Oil Jar, X0 Sub, [6] 6 5/8" Drill Collars, XO Sub, 6 1/4" ACC Jar. BHA= 261.01'. Overshot Dressed W/7" Grapple & Plain Control. RIH WI DP F/261'TI 5,568'. Kelly up. Break circ-get parameters, up wt = 175K, dn wt= 137K, rt= 155K, pump @ 5 bbl/min WI 115 psi SPP. Attempt T/ latch fish X6 setting dn 25K over dn wt. picking up W/45K over pull. Unable T/latch fish. Decision made T/ POOH. Circ- btms up. POOH F/TOF @ 5,594' T/3,800' @ report time. Lost 6813 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs =4 bbls/hr.J-bsk recovery Daily= 30#Total = 355.5#. Ditch &String magnets Daily= 94.5#Total =203.5#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0 total =130#.Tbg/ Blast jt intact Daily=0 Total = 675.9'. 11/14/14- Friday Continue pooh to BHA#13. Work and chk BHA#13 (cut lip guide egged grapple broken and 90% missing. Bowl also has id damage). Service rig while waiting on new 0/Shot bowl. Static loss rate @ 4 bph. M/up new 0/Shot bowl and guide loaded w/7" grapple. RIH w/ BHA#14 (RR#13 w/ new 0/Shot bowl and guide) t/ 5,568'. Kelly up and brk circ. Establish parameters. Work over TOF @ 5,594' swallow t/ 5,598' pull 25k over, bleed jars and set grapple. Attempt straight pull, @ 85k over grapple slipped. Attempted to re-engage X3 w/grapple slippage. Finish circ btm up. Pooh to BHA# 14. Work and chk BHA#14 (cut lip guide egged grapple missing. Bowl also egged and has id damage). Rig service. M/U BHA#15 - 8 1/8" Bowen Overshot+ Double Pin Sub+ Bit Sub+ 6 1/4" Bowen Lub. Bumper Sub+ 6 1/4" Bowen Oil Jar+XO Sub + [6] 6 5/8" Drill Collars+X0 Sub+ 6 1/4" Bowen ACC Jar. BHA= 226.29'. RIH F/ BHA W/DP TI 5,560'. Kelly up &get parameters, up wt= 173K, dn wt = 138K, rt wt = 154K, pump @ 5 bbl/min W/130 psi SPP, Rotate @ 20 rpm. Attempt to engage fish @ 5,594' W/ rotation on & off setting dn 10 to 30K. Unable to engage fish. Circ- btms up. Decision made to POOH. Blow dn T.D. POOH T/ BHA @ 226'. L/D BHA#15. M/U BHA#16 - 5 3/4" Bowen Overshot+ [1]jt 3 1/2" D.P. +X0 Sub +6 1/4" Bowen Lub. Bumper Sub+ 6 1/4" Bowen Oil Jar+X0 Sub + [6] 6 5/8" Drill Collars+XO Sub+ 6 1/4" ACC Jar. BHA= 253.39'. P/U [1] std DP & RIH. Complete rig service. Clean rig floor& adjust breaks. Well losses @ 4 bbl/hr. RIH F/347 T/ 5,561'. Kelly up. Get parameters- up wt= 170K, dn wt= 137K, rt= 155K, Pump @5 bbl/min W/ 115 psi SPP work over TOF @ 5,593' swallow T/5,394', see 200 psi pump pressure increase. Engage fish & pull 50K over to bleed jars. Straight pull 70K over see 10K drag T/5,564'then 5K drag over. Circ- btms up. Monitor well. Lost 6913 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs =4 bbls/hr.J-bsk recovery Daily= 0#Total = 355.5#. Ditch &String magnets Daily= 11#Total =214.5#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0 total =130#. Tbg/ Blast jt intact Daily= 0 Total = 675.9'. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/15/14-Saturday Continue finish circ btm up (ok). Monitor static well (Still @ 4 bph). Pooh t/ BHA#16 (wet). Work and chk BHA#16, shuck grapple, PJSM and prep to I/dn plug pipe w/possible trap BHP. L/dn+/-71' of 3.688" blast jts cut into 30' sections w/ pneumatic sawzall +9' stub of rotten 2-7/8" tbg total recovery= 80.00' of SS. P/up BHA# 17, w/8" guide on 5-3/4" 0/Shot loaded w/3-5/8" grapple. RIH w/ BHA#17,t/5,474' (see 30 units gas and oil at surface +/-3,800' on trip in hole). Kelly up and brk circ. Establish parameters. Gas units t/200 circ btm up at 16 bpm @ 1200 psi gas back to zero. Engage TOF @ 5,594' swallow t/5,601' w/ 100 psi increase in pump pressure. Pull 25k over bleed jars and set grapple.Attempt straight pull.At 50k, over weight fell back t/5k heavy. P/up+/-20' position tool jt, circ btm up @ 12 bpm @ 1200 psi. Pooh 1 std, blow dn TDS. L/dn 15' pup and single. Monitor static well @ 3 bph loss rate. Pooh t/ BHA#17 @ 261' and chg brk on dp. Work and chk BHA#17, shuck grapple. PJSM and prep to l/dn plug pipe w/possible trap BHP. L/dn +/-70' of 3.688" blast jts cut into 30' sections w/pneumatic sawzall + 72' of rotten 2-7/8" tbg total recovery= 142.00' of LS. Service rig. Clean rig floor. M/U BHA#18 - 5 3/4" Bowen Overshot w/8" guide + [2] 5 3/4" Overshot extensions+ [1]jt 3 1/2" D.P. +XO Sub + 6 1/4" Bowen Lub Bumper Sub+ 6 1/4" Bowen Oil Jar+ Pump Out Sub+XO Sub+ [6] 6 5/8" Drill Collars+X0 Sub+6 1/4" Bowen ACC Jar. BHA= 261.62' Overshot Dressed W/2 7/8" Grapple & Plain Control. RIH F/ BHA @ 261'T/Tag @ 5,604' setting dn 5/10K. Kelly up. Get parameters. Break circ- pumping @ 5 bbl/min W/115 SPP dn wt = 142K, up = 168K, rt wt= 155K. 4K free tq. rotate @ 20 rpm. Work past 5,604' start taking wt again @ 5,656' work to 5,663'. Adjusting pumps up to 15 bbl/min W/950psi, setting dn up to 25K over with no further progress. Circ- btms up seeing 120 units of gas. Monitor well, losses @ 5 bbl/hr. POOH F/5,663'T/ BHA @ 261'. Work& lay down BHA. Lost 6990 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs= 3.2 bbls/hr.J-bsk recovery Daily= 0 #Total = 355.5#. Ditch &String magnets Daily= 56#Total =270.5#. Scrap iron out of WP Non intact Tbg or blast Jt Daily=0 total =130#. Tbg/ Blast jt intact Daily= 222 Total = 897.9'. 11/16/14-Sunday Continue work and chk BHA#18. Recovered 5.80' rotten, twisted and shaved piece of 2-7/8" tbg. P/up& m/up BHA#19 w/8" guide w/5-3/4" 0/Shot loaded w/2-7/8" grapple and extensions and reinstall (4)j-bsk& string magnet back into BHA. RIH t/+/-5,036'. Monitor static well. Slip cut 125' drlg line w/3 bph loss rate. Adjust brakes. Clean rig floor. Continue RIH t/5,509'. Establish parameters. Wash in hole @ 16 bpm @ 1070 psi 1/5,509' started taking weight @ 5,661', work tools t/5,667'. Circ btm up and monitor static well @ 3 bph loss rate. Pooh t/ BHA and rotate brks on DP. Work &chk and clean BHA#19. Recovered 16# iron off string magnet, 20.5#out of junk bsks. 8" x 5-3/4" bell guide shows signs of junk into guide bell but not to grapple. P/up and M/up BHA#20= 8 1/2"x6" MM Shoe+ [2]jts 8 1/8" Washpipe +Top Sub+ Double Pin Sub + [4] Boot Baskets+ Bit Sub W/ Float +String magnet+ 6 1/4" Bowen Lub. Bumper Sub + 6 1/4" Bowen Oil Jar+XO Sub+ [6] 6 5/8" Drill collars+XO Sub+ 6 1/4" ACC Jar. BHA Length = 322.64'. RIH W/ 1 std DP. Service rig. Clean and organize rig floor. RIH F/417'T/Tag @ 5,613' setting dn 10K. Kelly up. Get parameters - up wt = 161K, dn wt = 129K, rt wt= 145K. pumping @ 16 bbl/min W/ 1250 psi SPP rotate @ 60 rpm W/8K free torque. Wash T/Tag @ 5,666'. Mill and clean up hole T/5,732' setting dn 3 T/5K while milling. F/TOF [S.S.] @ 5,674' T/5,732'. Hole was clean picking up &down W/ rotation off, max gas was 550 units. Circ- 1 1/2 btms up @ full rate, monitor well, losses increased to 30 bbl/hr. Pooh F/5,732'T/ BHA @ 322'. Work& L/D BHA#20 @ report time losses to well = 20 bbl/hr. Lost 7071 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs= 3.4 bbls/hr.J-bsk recovery Daily = 20.5 #Total = 376#. Ditch &String magnets Daily= 160#Total =386.5#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0 total =130#.Tbg/ Blast jt intact Daily= 222 Total = 897.9'. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/17/14- Monday Finish chk and cleaning BHA#20. Recovered 54# iron off string magnet, 85# iron out of junk bsk and 106#off ditch magnets. Had 4 different strings in shoe and 1/2 of XA sleeve that had come apart @ service brk total = 54'. ETOF 5,732' SS and 5,739' LS. Clear/clean rig floor. Service rig. P/up and M/up BHA#21 = 8-1/2"x7" MM Shoe + [3]jts 8 1/8" Washpipe +Top Sub + Double Pin Sub + [4] Boot Baskets+ Bit Sub W/ Float+String magnet + 6 1/4" Bowen Lub. Bumper Sub + 6 1/4" Bowen Oil Jar+XO Sub+ [6] 6 5/8" Drill collars+XO Sub+ 6 1/4" ACC Jar. BHA Length = 354.01'. RIH w/ BHA #21 t/5,724' and Kelly up. Establish parameters- up wt= 170K, dn wt= 132K, rt wt= 150K. Pumping @ 16 bbl/min W/ 1175 psi SPP rotate @ 60 rpm W/ 10K free torque. Wash T/Tag @ 5,732'. Mill over TOF SS continue wash over t/est TOF @ 5,739' LS. Continue washing over t/5,761' w/high gas of 656 units & loss rate of+/-32 bph varying. Getting a lot of sand fill back. Mill died and had clean p/ups. Circ btm up w/no gas units. Over pulled 25k at 5,732' ream and wash back over TOF @ 5,732' and 5,739'. Squat dn 50k P/up bleed jars @ 25k and straight pull. At 75k over, lost all over pull. Attempt to find TOF several times, no-go. Circ btm up w/ no gas units. Rack back one std blow dn TDS. Monitor static well w/27 bph loss rate. Pooh t/ BHA(pulled 50k briefly @ 850'). Work chk & clean BHA#21. Recovered 58# iron off string magnet, 64#out of junk bsk &wash pipe MT. Monitor static well while servicing rig @ 22 bph and clean clear floor. M/up BHA#22 (RR of#21 w/new shoe). RIH w/ BHA#22 t/5,724'. Kelly up & establish parameters. Lost 7602 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs = 22.0 bbls/hr.J-bsk recovery Daily= 149#Total = 525#. Ditch & String magnets Daily= 182#Total =568.5#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0 total =130#.Tbg/ Blast jt intact Daily= 54 Total = 951.9'. 11/18/14-Tuesday Wash in hole f/ 5,724' @ 16 bpm. At 1,175', did not encounter either TOF @ 5,732' or 5,739' to tag @ 5,757' (4') high. Attempt mill/wash over dual fish (at XA sleeve and XN nipple side by side)f/5,758' t/5,761' having frequent stalls w/ occasional 10-20k over pulls. Pull one std, blow dn TDS and monitor static well w/ 19 bph loss rate. Pooh t/ BHA#22. Work, chk and clean BHA#22. Recovered 38# iron off string magnet and 22#iron out of junk bsk and missing 1/2 of XA sleeve @ 1.63' and XN nipple @ 1.26' total = 2.89' balled up in shoe. P/up BHA#23 (RR#22 w/8-1/2" X 6-1/2" new burn shoe) and one std DP. Installed softener under TDS service loop. Service rig. Lubricate & inspect crown saver bell system. Continue RIH t/ 5,724'. P/up 2 singles. Kelly up and brk circ. Establish parameters- up wt = 168K, dn wt = 138K, rt wt = 148K. pumping @ 16 bbl/min W/ 1200 psi. Rotate @ 60 rpm W/9K free torque. Wash T/Tag @ 5,761' start to mill over fish. P/up off btm and trouble shoot SCR cooling system. Repair same. Continue wash over t/5,762' w/ high gas of 10 units & loss rate of+/-35 BPH. Getting very little sand fill back. Mill died and had clean p/ups. Circ btm up w/ no gas units. Monitor well while blowing down top drive. Static loss rate = 27 BPH. POOH with BHA#23.Test choke manifold 250 L/2500 H on TOH. Work, chk and clean BHA#23. Recovered 30# iron off string magnet and 19# iron out of junk bsk and recovered 1.3' and XN nipple @ .80' total = 2.1' balled up in wash pipe shoe. Recovered 53 lbs off of ditch magnets. Clear rig floor. Pull wear bushing. Flush tubing head profile and stack. Test BOPE at 250 L/2500 H. AOGCC (Jim Regg) waived witness on 11-17-14 at 16:27 hrs. Lost 8201 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total.Avg losses to well 24 hrs = 25.0 bbls/hr. J-bsk recovery Daily= 41 #Total = 566#. Ditch & String magnets Daily= 121#Total =689.5#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 30 total =160#. Tbg/ Blast jt intact Daily = 54 Total = 951.9'. • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/19/14-Wednesday Continued testing__BOPE.on 5" &_2-7/8" test jts._130PE at 250 L/2500 H.AOGCC(Jim_Regg) waived witness on 11-17-14 at INY 16:27 hrs. Continue to have problems getting test plug to seal. (Having to dump salt on plug to get test). Continued monitoring losses via trip tank on annulus valve @ 22 BPH loss rate. Fwd plan to chg/out tbg spool once a surface test of .0' ID of test plug/hanger is confirmed good. R/dn test equipment and test gas alarms. Set wear bushing. P/up M/up BHA# 24 = 8-1/8" Overshot w/cut lip guide loaded w/2-7/8" grapple. RIH and tag TOF at 5,762'. Parameters: 16 BPM/1070 psi, 20 RPM/6 K torque, P/U 170 K, S/0 136 K, Rt Wt 152 K. Attempt to work over fish several times. Circulate bottoms up with no gas units. Blow down top drive. POOH to BHA. Work, chk and clean BHA#24. Recovered 37# iron off string magnet and 7.5# iron out of junk bsk and recovered .68' balled up in guide shoe. Recovered 9#off of ditch magnets. Loss rate = 27 BPH. Make up BHA#25: 8 1/2" concave mill, six boot baskets bit sub, string magnet, bumper sub/oil jars, XO, 6 ea. 6 5/8" drill collars, XO, accelerator jars = 263.05. Loss rate 27 BPH. Service rig and equipment. RIH with BHA#25. Establish parameters: P/U 172 K, S/0 140K, Rt 155K at 80 RPM and 11K torque. 10 BPM/625 psi and 16 BPM/1450 psi. Mill junk/fish from 5,762' to 5,777' with 4- 14 K WOB. 195 units gas max. Loss rate 27 BPH. Circulate bottoms up at 16 BPM/1450 psi. Lost 8820 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs= 25.0 bbls/hr.J- bsk recovery Daily = 53 #Total = 619#. Ditch &String magnets Daily =46#Total = 735.5#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 8 total =168#.Tbg/ Blast jt intact Daily= 54 Total = 951.9'. 11/20/14-Thursday Spot 15 bbl sized salt pill on bottom at 5,777'. Blow do TDS monitor static well @ 18 BPH loss rate. POOH t/ BHA. L/dn, chk and clean BHA#25. Recovered 41# iron off string magnet and 35# iron out of junk bsk and 52#iron off ditch magnets. Junk mill 70% used up. Static losses @ 15 bph. P/up M/up BHA# 26 8-1/2" X 6-1/2" (Opti Cut) shoe, jt 8-1/8" wp, top sub, dbl pin, (6) 7"j-bsk, BS w/float, string magnet, 6-1/4" BS and OJ, XO, (6) 6-3/4" dc's, XO, acc jar= 299.01'. RIH p/up single t/5,718'. Kelly up. Brk circ @ 16 bpm @ 1150 psi. Establish parameters up/dn/rot 175/130/150k @ 60 rpm @ 10.8k free rotating torque. Wash in hole &tag @ 5,777'. Wash over obstruction and dual tbg string t/5,790' and clean sand out. W/ high gas of 139 units and loss rate of 6 bph. Mill 6-1/2" fish neck on parallel flow head f/ 5,790' t/5,793'. No appreciable progress at 5,793'. High gas of 385 units. Circulate at 16 BPM/1250 psi until back ground gas is 0 units. Install Voorhees crown saver. 29 BPH static loss rate. POOH to BHA. L/dn, chk and clean BHA#26. Recovered 41.5# iron off string magnet and 32# iron out of junk bsk and 44# iron off ditch magnets. Also recovered 7.41' and 8.72' of tubing. Mill 40%worn. Static loss rate @ 28 BPH. P/U M/U BHA#27: 8-1/2" X 6-1/2" (Opti Cut) shoe, jt 8-1/8" WP, top sub, dbl pin, (6) 7"j-bsk, BS w/float, string magnet, 6-1/4" BS and OJ, XO, (6) 6-3/4" DC's, XO, Acc jar= 300.21'. RIH to 5,734'. Kelly up. Break circ @ 16 bpm @ 1150 psi. Establish parameters up/dn/rot 175/130/150k @ 80 RPM @ 10.8k free rotating torque. Engage top of fish at 5,792'. Mill 6-1/2" fish neck on parallel flow head f/5,792' t/5,793'. Using various parameters. Loss rate 27 BPH. Max gas 385 units. Lost 9359 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs= 22.0 bbls/hr.J-bsk recovery Daily= 67#Total = 686#. Ditch &String magnets Daily= 178.5#Total =914#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0 total =168#. Tbg/ Blast jt intact Daily= 16.13 Total = 968.03'. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/21/14- Friday Attempting Mill 6-1/2" fish neck on parallel flow head f/5,792't/5,793'. Using various parameters, with no appreciable progress. Circ BTM up @ 16 bpm, blow dn TDS & monitor static well @ 25 bph loss rate. POOH to BHA. Chk, clean BHA# 27. Recovered 20# iron off string magnet, 5#iron out of junk bsk and 53#iron off ditch magnets. Wash pipe empty and shoe green. P/up and M/up BHA#28, 8-1/8" 0/shot w/extensions and 8-1/8" cut lip guide loaded w/2-7/8" grapple. W/ losses @ 22 BPH. RIH w/ BHA#28 t/5,661'. Service rig. RIH and Kelly up at 5,725'. Establish parameters up/dn/rot 175/130/150k @ 10 RPM @ 10.8k free rotating torque. Engage top of fish at 5,792' with 10K set down. See no pressure increase with 30K set down. Pick up with no overpull. CBU with no gas units. POOH to BHA. Check and clean BHA#28. Recovered 10# iron off string magnet, 5#iron out of junk bsk and 24# iron off ditch magnets. Overshot empty. Loss rate at 18 BPH. P/U and M/U BHA#29: 4 11/16" Short catch overshot, X0, 1 ea 3 1/2" DP, X0, sub, 2 ea boot baskets, bit sub, string magnet, BS/OJ, XO, 6 ea 6 1/2" DC's, XO, Acc jars= 280.74. Loss rate at 25 BPH. RIH with BHA#29 to 5,746'. Kelly up at 5,746'. Establish parameters: up/dn/rot 175/135/155k @ 20 RPM @ 5K free rotating torque. Engage fish at 5,793'. Set down and attempt to catch fish with 10k- 30K set down and slight rotation while circulating at 16 BPM/1050 psi. Saw slight increase in pump pressure but went away after picking up. No over pulls after several attempts. CBU at 16 BPM/1050 psi while positioned 4" above fish at 5,793'. POOH to BHA. Check and clean BHA#29. Recovered 8# iron off string magnet, 0# iron out of junk bsk and 0# iron off ditch magnets. Overshot empty. Loss rate at 27 BPH. Clear and clean rig floor. Pick up BHA#30 reverse circulating junk basket. Lost 9930 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs = 22.0 bbls/hr.J-bsk recovery Daily= 10#Total = 696#. Ditch &String magnets Daily= 115#Total = 1029#. Scrap iron out of WP Non intact Tbg or blast it Daily= 0 total =168#.Tbg/ Blast jt intact Daily=0 Total = 968.03'. 11/22/14-Saturday P/U M/U BHA#30: 8 1/4" x 6" RCJB, X0, 2 ea boot baskets, bit sub, string magnet, BS/OJ, XO, 6 ea 6 1/2" DC's, X0. Acc jars = 253.46. Service rig, blocks, TDS, crown, and DWK. Replace hyd hose on ST-80. Chk bope controls. Remove mule from derrick to repair. RIH w/ BHA#30 to 5,719'. Kelly up. Establish parameters up/dn/rot 167/135/150k @ 60 RPM @ 8.2k free rotating torque. Pump rate 5 bpm -18 bpm. Wash in hole reversing @ 18 bpm @ 1460 psi tag @ 5,793' work tools. Mill f/5,793' t/5,793.5' getting erratic torque & 50k over pulls. At times appears to have drug fish up hole t/5,779' and taking 30k to push back dn. (last movement pulled up hole t/5,779' before losing drag). CBU with only high gas of 8 units. Monitor static well @ 26 BPH loss rate. POOH to check tools to BHA. Check and clean BHA#30. Recovered 2# iron off string magnet, 2# iron out of junk bsk and 0# iron off ditch magnets. Recovered 16' seal assembly and parallel flow head. Loss rate at 26 BPH. Install crown saver bell and derrick mule. P/U M/U BHA#31: 8 1/2" x 6" PRT mill, 6 ea boot basket, bit sub, string magnet, BS/0J, X0, 6 ea 6 1/2" DC's, X0, Acc jars = 264.12. RIH w/ BHA#31 to 5,730'. Kelly up. Establish parameters up/dn/rot 167/135/150k @ 60 RPM @ 8 K free rotating torque. Pump rate 5 BPM -16 BPM, 600- 2000 psi. Mill on packer at 5,795' - 5,797' with 10K WOB. Packer came free and moved downhole 3' and no over pull up. 75 units gas at bottoms up. Circulate bottoms up at 8 BPM/600 psi. 0 gas units at bottoms up. POOH slowly with BHA #31 to BHA. Work BHA and lay down recovered fish/packer(Model 'F' permanent packer) .81'. 35#of iron off of string magnet, 12#out of boot baskets, 26#off ditch magnets. New TOF is 5,811'. P/U M/U BHA#32: 8 1/2" x 7 1/4" drag tooth shoe, 8 ea joints wash pipe, 2 ea wash pipe ext, top sub, XO, 6 ea boot baskets. bit sub, string magnet, BS/OJ, XO, 6 ea 6 1/2" DC's, X0, Acc jars = 525.10. Lost 10,427 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs= 22.0 bbls/hr.J-bsk recovery Daily= 12#Total = 708#. Ditch &String magnets Daily= 63# Total =1092#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0 total =168#.Tbg/ Blast jt intact Daily=0 Total = 968.03'. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/23/14-Sunday P/U M/U BHA#32: 8 1/2" x 7 1/4" drag tooth shoe, 8 ea joints wash pipe, 2 ea wash pipe ext, top sub, XO, 6 ea boot baskets, bit sub, string magnet, BS/OJ, XO, 6 ea 6 1/2" DC's, XO, Acc jars= 525.10. Service rig.Test crown saver bell system (ok). Continue RIH w/ BHA#32 t/5,802' and Kelly up and Brk Circ. Establish parameters up/dn/rot 155/124/135k @ 60 RPM @ 9.0k free rotating torque. Pump rate 16 bpm @ 1440 psi wash down tag @ 5,807'. Work over TOF. Wash over fish f/5,807' t/6,022' with high gas of 132 units. Loss rate @ 38 BPH getting back little sand, paraffin and iron. Had increase in sand returns and having to run more WOB f/top of perfs @ 5,825'. Started seeing torque @ 6,000' & stalls t/ 15k. Pump (2) 10 bbl high vis sweep to clean hole and carrying 20-30 units back ground gas. Circ clean, w/28 BPH loss rate. Blow dn TDS and monitor static well @ 29 BPH. 0 units back ground gas. POOH with BHA#32. Work BHA and lay down used up wash pipe shoe. 12#of iron off of string magnet, 12#out of boot baskets, 84#off ditch magnets. 19 BPH loss rate. M/U BHA#33 (new shoe only). BHA#32: 8 1/2" x 7 1/4" flat bottom shoe, 8 ea joints wash pipe, 2 ea wash pipe ext, top sub, XO, 6 ea boot baskets, bit sub, string magnet, BS/OJ, XO, 6 ea 6 1/2" DC's,XO, Acc jars= 526.79. Service rig. RIH with BHA#33 to 5,790'. Break circulation at 16 BPM/1350 psi. Lost 11,026 bbls 8.6 ppg 3% KCL and 509 bbls sized salt pill total. Avg losses to well 24 hrs = 22.0 bbls/hr.J-bsk recovery Daily= 12 #Total = 720#. Ditch &String magnets Daily= 96#Total =1188#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0 total =168#. Tbg/ Blast jt intact Daily= 0 Total = 968.03'. 11/24/14- Monday Continue wash dn @ 16 BPM/1375 psi f/5,708' t/5,821' w/ no indication of top of fish @ 5,807'. Initiate rotation, wash dn tag @ 6,021'. Mill wash over fish f/6,021't/ pkr @ 6,063'. Had hard milling f/6,021' t/6,029', easy milling f/6,029' t/ 6,040', hard milling f/6,040' t/6,044' (XA Sleeve) easy milling 6,044' t/ pkr @ 6,063'. Circ btm up. Gas spiked t/ high of 547 unit and oil to surface. Pump 10 bbl high vis sweep around w/50% increase in cuttings. Circulate clean and balance 30 bbls sized salt pill on bottom. POOH 3 std and above fish. Blow dn TDS& monitor static well @ 18 bph loss rate. Continue POOH t/ BHA. L/dn and chk BHA#33. Mill 20%wore w/ ID taper. Recovered 32#off string magnet, 30#out of J- bsk& 8.5#off ditch magnets. Loss rate @ 17 BPH. P/up BHA#34 = 5-3/4" 0/shot w/8" bell cut lip guide w/pack-off and extension loaded w/3-3/4" grapple. Service rig. RIH with BHA#34 t/5,725'. Kelly up. Break circulation @ 16 BPM/980 psi. Establish parameters Up/Dn/Rot= 175/135/155. Engage TOF at 5,807' with 300 psi pressure increase. Bleed off pressure. Chase fish down hole to 5,831' and set down 10K. Pull uphole +/-35' with no over pull with 5K extra weight. Stand back 1 stand. Drop ball/open P/O sub with 750 psi. Circulate 2 bottoms up with max gas of 556 units. Monitor well. Static loss 22 BPH. POOH to BHA. Work BHA#34. Recovered XA sleeve and 10 blast joints= 205'. New estimated TOF 6,012'. 14 BPH loss rate. P/U M/U BHA#35 = 5-3/4" overshot w/8" bell cut lip guide w/ pack-off and extension loaded w/3-5/8" grapple. RIH with BHA#35 to = 5,960' (pick up 6 joints of DP). Lost 11,460 bbls 8.6 ppg 3% KCL and 554 bbls sized salt pill total. Avg losses to well 24 hrs= 22.0 bbls/hr.J-bsk recovery Daily= 30#Total = 750#. Ditch & String magnets Daily= 40.5#Total =1228.5#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0 total =168#.Tbg/ Blast jt intact Daily= 199 Total = 1167.03. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/25/14-Tuesday Pick up 3 joints drill pipe. Kelly up. Break circulation @ 4 BPM/80 psi. Establish parameters Up/Dn/Rot= 180/142/155. Engage TOF at 6,038' (expected TOF 6,012'). Set down 10k with no change in pump pressure. Pick up with no over pull. Set down 20K with slow rotation and no increase in pump pressure. Had high gas of 340 units and tapered off to 0 units. CBU at 10 BPM/550 psi and balanced 30 BBL sized salt pill on bottom. Blow dn TDS& monitored static well @ 20 BPH. POOH t/ BHA. Work and chk BHA#35. Had blast jt hanging out of overshot. Cut off blast jt 1' below overshot. Lay down jars, bumper sub and overshot with small fish in it. Lay dn blast jt, XO, XA sleeve, and 3.43 section of pup jt. PU jars and break out overshot to recover 5.75 more blast jt.Total fish recovered 28.38'. New TOF= 6,066'. Well taking 17 BPH. PU BHA#36. 8 1/2" bit, Csg scraper, Bit sub w/float,Jars, Bumper sub, XO, 6 DCs, XO. = 213.49. RIH to 4,855'. Circ hole clean at 680 GPM and 940 psi. Got a high of 6 units of gas and very small amount of sand and scale. Continue to circ at 2.5 BPM while cutting drilling line. [Losses to well 15.4 BPH]. POOH and lay down casing scraper assembly. P/U bit, bit sub, 2 stands DC's, 5 stands DP and RTTS. RIH and set RTTS at 4,705'. P/U 160K, S/O 132K. Test 9 5/8" casing at 1560 psi on chart for 30 minutes. Good test. Bleed off pressure. Release RTTS. Blow down lines. 18 BPH loss rate. POOH with RTTS. Make up RTTS with by-pass. RIH and set same 2 stands in. POOH. Close blind rams. Test storm valve at 1500 psi. Pull wear bushing. Clear floor. Nipple down BOPE. Lost 11,809 bbls 8.6 ppg 3% KCL and 577 bbls sized salt pill total.Avg losses to well 24 hrs = 22.0 bbls/hr.J-bsk recovery Daily= 0#Total = 750#. Ditch &String magnets Daily= 20.5#Total =1229#. Scrap iron out of WP Non intact Tbg or blast Jt Daily=0#total =168#.Tbg/ Blast jt intact Daily= 28.38 Total = 1195.41'. 11/26/14-Wednesday Nipple down BOPE. Make sure pressure is bled off void in spool. RU to PU stack. Break bolts on top and bottom of spool. A couple loose bolts on each. PU on stack breaking loose bottom flange. Set down on boards and pull top bolts. Raise - 1� stack up out of the way. Pull old spool off wellhead. Inside rings and seals from spool stayed on csg stub. Run in LD N screws on old spool and pull it up out of the wellhead room. Work seals and rings off csg stub. Get the 4 old bolts out of "f' the csg head_and __prep head for new tb_g_spool. RU and get spool set on csg head. Set BOPs on and bolt down same. Nipple up the rest of the BOPS.Test spool void to 250 psi low and 2500 psi high. Make up test joint and rig up test �/ manifold. Test all BOPE components at 250 L/2500 H with 5" and 2 7/8" bulars. Good test. Witness of test waived by Mr.Jim Regg, AOGCC. Rig down test joint and test equipment. Set wear ri g. Organize and clean rig floor down to and including well head room. Hold PJSM. Pick up 24 joints of 5" drill pipe an stand back in derrick. Housekeeping and maintenance projects. Lost 11,928 bbls 8.6 ppg 3% KCL and 577 bbls size salt pill total. Avg losses to well 24 hrs= 22.0 bbls/hr. J-bsk recovery Daily= 0#Total = 750#. Ditch & String magnets Daily= 0#Total =1229#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0#total =168#. Tbg/ Blast jt intact Daily =0 Total = 1195.41'. (6 I"-Leity Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/27/14-Thursday Working on several maintenance projects while working on accumulator. Replace railroad unions. Install new KR valve on annular side. Install new solenoid in control box. Drain and blow dn entire hyd system and fill system with new oil. Clean 3 suction screens and storage bottle discharge screen. Press up system and check for leaks. System holding pressure. Operate BOP equip from touch screen on rig floor. Blind rams would not operate.Trouble shoot and found bleed solenoid hooked up backwards. Test entire system and adjust 4 way valves. Everything working good. PU packer retrieving stinger and RIH. Engage packer. MU floor valve in top of stand. Screw into storm valve to open bypass. Open floor valve and pipe is on a vac. Pull 6k over up wt and release packer.Took 46 bbls to fill the hole. Monitor well and POOH laying dn Storm Valve and Packer. Stand back DP and DCs. [Loss rate 24.8 BPH]. PU BHA#37. 8 1/2 X 6 Opti cut mill shoe, 2 jts 8 1/8 WP, Top sub, Dbl pin sub, Six 7" boot baskets, Bit sub w/float, String magnet, Bumper sub,Jars, XO, Six 6 5/8 DCs, XO, Acc jars. = 330.67. Service rig. RIH with BHA#37 to 6,017'. Establish parameters up/dn/rot 165/135/152k @ 60 RPM @ 9.0k free rotating torque. Pump rate 16 BPM @ 1200 psi. Circulate bottoms up with 557 units gas max. Loss rate 16 BPH. Engage TOF at 6,063'. Mill packer from 6,063' - 6,067' at 60 RPM/4K-18K WOB. Broke free and pushed down hole to 6,079' and set down 30K. Flow rate increased from 50%to 70%. Shut well in and circulate through gas buster at 8 BPM/500 psi. 620 units gas at bottoms up. Continue circulating until units of gas<30. Shut down. Open annular preventer. Set back down on fish at 6,079' with 30K. Pick up with 15K extra weight. Pull stand and check for swabbing, okay. CBU at 8 BPM/350 psi with 40 units gas max. Loss rate 47 BPH. Pull 7 stands above top perfs at 5,280'. Spot 22 bbl sized salt pill. Monitor static loss rate at 18 BPH. POOH with BHA#37. Lost 12,124 bbls 8.6 ppg 3% KCL and 597 bbls sized salt pill total. Avg losses to well 24 hrs= 24.0 bbls/hr. J-bsk recovery Daily= 0#Total = 750#. Ditch &String magnets Daily= 70#Total =1299#. Scrap iron out of WP Non intact Tbg or blast Jt Daily=0#total =168#. Tbg/ Blast jt intact Daily= 0 Total = 1195.41'. 11/28/14- Friday POOH to BHA. Work BHA. Clean string magnet, lay dn boot baskets, and break mill shoe. Shoe was worn down 1" and was worn on a taper or bevel on the outside. Recovered 40 lbs metal off string magnet and 6 lbs out of the boot baskets. Hole taking 18 BPH. PU BHA#38. 6" short catch overshot, XO bushing, 2 jts of 8 1/8 WP, Top sub, Dbl pin sub, Bit sub w/ float, String magnet, Bumper sub,Jars, 6 DCs, XO, Acc jars. = 303.53. Service rig. RIH to 5,967'. Get up and down wts w/ and without pump. 80 spm 350 psi. Up 180k and dn 142k. Wash dn to 6,084' and it started taking wt. Set 15k dn and wt fell off. Slack off 6,085' and set dn another 15k. Pump press came up 100 psi. PU and pull 20k over. Slack back off and set 30k dn. PU and work at 35k over pull several times and packer started moving up hole. Continue working stand up while circ. Pulled up to 45k over several times to work through. Circ bottoms up.The highest gas units were 28. Monitor well, 14 BPH loss, and blow dn TD. POOH to BHA. Had to work through several spots pulling from 20k to 60k over to work through them up to 5,706'. After that we just had 10k to 15k over pulls. Work BHA. Lay down fish. Recovered 17.04' partial seals, 10.74' pups above and 5.75' of packer. String/ditch magnet= 149#. 15 BPH loss rate. New TOF+/- 6,090'. P/U M/U BHA#39: 8 1/2" MM Concave junk mill, 5 ea boot baskets, bit sub, string magnet, BS/OJ, XO, 6 ea 6 1/2" DC's, X0, Acc jars= 259.18. Service rig. RIH with BHA#39 to 6,040'. Establish parameters up/dn/rot 184/145/162k @ 60 RPM @ 11.0k free rotating torque. Pump rate 15 BPM @ 1050 psi. Engage top of junk/fill at 6,079'. Mill 6,079' to 6,228' using various pump rates and WOB (4K- 16K). 520 units max gas. 42 BPH loss rate. Lost 12,538 bbls 8.6 ppg 3% KCL and 597 bbls sized salt pill total. Avg losses to well 24 hrs= 24.0 bbls/hr.J-bsk recovery Daily= 0#Total = 750#. Ditch & String magnets Daily= 149#Total =1087#. Scrap iron out of WP Non intact Tbg or blast Jt Daily=0#total =0#.Tbg/ Blast jt intact Daily= 33.53 Total = 1228.94. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 11/29/14-Saturday Circ and pump 10 bbl high vis sweep. Getting back a lot of sand. Got back a good increase in sand when sweep came around. Mill 6,228' to 6,461' using various pump rates and WOB (4K- 16K). 500 units max gas. 42 BPH loss rate when we first cleaned out to the perfs and 29 BPH after we got to bottom. Pump high vis sweep and circ 1 1/2 bottoms up. Had a 150% increase in fines when sweep came back. Monitor well and the loss rate was 28 BPH. Pull 5 stds [pull 15k over at 6,123'] Monitor well while we serviced the rig. Loss rate 18 BPH. RIH and tag bottom w/ no fill. Circ bottoms up to check for gas. No sand and had a high of 20 units of gas. POOH to BHA. Loss rate 24 BPH. Work BHA. Stand back DCs. Clean String magnet [Recovered 73.4 lbs]. Lay down junk mill [50% used]. Lay down boot baskets [Recovered 143 lbs]. Clear tools off floor. Unload boat. Rack and strap 2 7/8 tbg. Back load boat. [Also rigging up E-Line while working boat]. Start RIH w/ E-Line. Run GR/CCL from 6,460' to 1,000'. Rig down e-line. P/U M/U BHA#40: 8 1/2" bit, bit sub, string magnet, BS/OJ, XO, 6 ea 6 1/2" DC's, XO = 220.91. RIH with BHA#40 to 6,382'. Establish parameters up/dn/rot 195/145/164k @ 50 RPM @ 10K free rotating torque. Pump rate 16 BPM @ 1050 psi. Engage PBTD at 6,461'. No fill. Circulate surface to surface volume with 15 units of gas and no sand over shakers. Loss rate 16 BPH. Hold PJSM. POOH laying down drill pipe. 18 BPH loss rate. Lost 13,019 bbls 8.6 ppg 3% KCL and 597 bbls sized salt pill total. Avg losses to well 24 hrs = 24.0 bbls/hr. J-bsk recovery Daily = 143#Total = 893#. Ditch & String magnets Daily= 385.5#Total = 1472.5#. Scrap iron out of WP Non intact Tbg or blast it Daily= 0#total = 0#. Tbg/ Blast jt intact Daily= 0 Total = 1228.94. 11/30/14-Sunday POOH laying down drill pipe and BHA. 18 BPH loss rate. Recovered 44.5 lbs metal off string magnet. Clear floor of tools. Move 3 stands of 5" DP in derrick to make pocket for tbg. RU tbg equip. RIH w/two stands of 2 7/8 that has been standing back and lay them down. Hold PJSM. MU XOs on string magnet and RIH picking up 2 7/8 tubing to 6,020'. 16 BPH loss rate. POOH standing tubing back in derrick. 20 BPH loss rate. Recovered 4.5 lbs off magnet. 18 BPH loss rate. Clear rig floor. Make bar drop assembly. Make up safety joint and stage in v-door. Hold PJSM with all to be involved in picking up perf gun assembly. RIH picking up perf guns. 22 BPH loss rate. Lost 13,483 bbls 8.6 ppg 3% KCL and 597 bbls sized salt pill total. Avg losses to well 24 hrs= 19.0 bbls/hr.J-bsk recovery Daily= 0#Total = 893#. Ditch &String magnets Daily= 58.5#Total = 1531#. Scrap iron out of WP Non intact Tbg or blast it Daily=0#total = 0#. Tbg/ Blast jt intact Daily= 0 Total = 1228.94. P Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 12/01/14- Monday Continue RIH picking up perforation gun assembly,..MU firing head, ported flow sub, and RA marker. [Loss rate 24 BPH]. Hold PJSM. RIH w/tbg out of the derrick to 6,406'. Space out and set on depth with bottom shot at 6,421' as per tbg tally. RU e-line and run GR/CCL to correlate. Send log to town to verify moving guns up hole 4'. POOH w/e-line and rig down same. RU bar dropping assem loaded with bar. Move pipe up hole 4'. [TS 4,746'-BS 6,422']. Close annular and RU to circ through choke. Drop bar and guns fired in 2 min and 22 sec. Pump down tbg to fill hole.Took 26 bbls to get returns back to shakers through poorboy degasser pumping at 3 BPM and 250 psi. Reduce pump rate to 1 1/2 BPM and 100 psi for 15 min then shut down circulation for 15 min to let gas swap places w/fluid. No pressure build up at choke. Start pumping again and increase rate to 4 BPM. After pumping 245 bbls gas had built up to 475 units and we started getting oil back at the shakers. Continue circ with traces of oil at shakers and a high of 607 units of gas. Continue to circ w/gas going down to 150 units and back up around 500 units several times. Shut pump down and shut in to see if pressure built up. Pressure built up to 40 psi in about 20 min. Open choke and bring pump back up to 4 BPM. Units of gas built back up to 500 within 5 min. Continue circulating at 5 BPM/830 psi with high gas of 480 units tapering off to 300 units. Shut down pump. Open annular preventer. Circulate gas out at 7 BPM/1380 psi from circulating port at 4,700' allowing oil/gas to migrate up from bottom shot at 6,422'. Not able to get gas below 450 units after several circulations. Loss rate 6 BPH. Weight up to 8.9 ppg 3% KCL while circulating at 5 BPM/730 psi. Back ground gas units down to 320. Loss rate now at 24 BPH. Gas breaking out at surface. Continue circulating at 5 BPM/730 psi while weighting up to 9.1 ppg 3% KCL. Back ground gas units down to 250 units and gas continues breaking out at surface. Loss rate 40 BPH. Pump 20 bbl sized salt pill and circulate in at 1 BPM. Lost 14,144 bbls 8.6 ppg 3% KCL and 597 bbls sized salt pill total. Avg losses to well 24 hrs = 19.0 bbls/hr. J-bsk recovery Daily= 0#Total = 893#. Ditch &String magnets Daily=4#Total = 1535#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0#total =0#. Tbg/ Blast jt intact Daily=0 Total = 1228.94. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 12/02/14-Tuesday Circulating second 20 bbl sized salt pill at 1 BPM. 9.1 ppg 3% KCL fluid weight system. Circ slow to let 10 ppg pill fall and find the loss zone. Continue circ at 1 BPM w/gas running from 180 to 245 units. Losses went down to 25 BPH. Stringing in salt to bring the wt up to 9.2 while waiting on boat w/20 more pallets of salt. Boat arrived w/salt. Continue circ at 1 BPM and stringing in salt. Wt up pit to 9.4 ppg and batch up 40 bbls of 9.4. Ship up f/ pill pit to active system. Gas started to increase. Went up to 350 units. Increase pump rate to 3 BPM, 300 psi. Pumping 9.4 dn and getting 9.2 back. Gas increased to 650 units then started back down and went to 10 units as we circ 9.4 down. Increase pump rate to 4 BPM, 500 psi. Gas down from 2 to 10 units. Started to notice a trend. 15 to 20 min after we worked the pipe we get a spike or gas increase. At 1515 hrs we started working the pipe constantly. The gas came up to a high of 619 units with a 9.4 KCL. Loss rate 24 BPH. Started bringing the wt up to 9.5 ppg at 1530 hrs. Circ 4 BPM at 530 psi. Got wt up to 9.5 all the way around. Shut down pump and monitor for loss rate. Well taking 40 BPH. Spot 30 bbl SSP. Rig dn circ head. Lay dn space out pups. POOH standing back 2 7/8 tbg. F/6,378' T/5,433'. R/U Cmt line & pump 95 bbls total @ 6.6 bbl/min W/ 1100 psi and spot 25 bbls clean 9.5 3% KCL in tubing to stop flow back. POOH. Standing back 2 7/8" tubing F/5,433'T/1,670'. PJSM. L/D R/A sub+ 2 jts tubing+ Ported sub+ 1 jt tubing+safety sub & bar. M/U Safety jt. C/O Elevators. POOH laying down (79) 4 1/2" spent guns, all shots fired. Losses= 28 bbls/hr while POOH. Break dn 2 7/8" safety jt. Remove tools, clear& clean rig floor. Work boat bring on ESP equipment. Lost 14,868 bbls 3% KCL and 699 bbls sized salt pill total.Avg losses to well 24 hrs= 30 bbls/hr.J-bsk recovery Daily= 0#Total = 893#. Ditch &String magnets Daily= 0#Total = 1535#. Scrap iron out of WP Non intact Tbg or blast Jt Daily= 0#total = 0#. Tbg/ Blast jt intact Daily= 0 Total = 1228.94. 12/03/14-Wednesday PU and break dn bar dropping assem. Pull wear ring. Prep to PU ESP completion. Set spools in position and get everything warmed up. Make sure all equip is on platform. Have PJSM with everyone involved. Start picking up and putting ESP together. ESP is 75%together at 1430 hrs. Hole taking 16 BPH. Run tests on ESP equip. Gauge is reading way to high [Reading 700+degrees]. Pull up and change out gauge. Shroud was so tight it had damaged the lines when ESP was pulled out to change our gauge. Decision was made not to run shroud. Lay dn shroud. Get everything tied back in and test everything again. Run down hole pumps. Change elevators. P/U single of 2 7/8" tubing. M/U discharge head and test line's. PJSM. RIH W/ ESP assembly W/2 7/8" L-80 8rd EUE tubing F/145'T/4,300' at report time. Installing clamps as needed per Summit and testing ESP every 1,000'. Losses @ = 22 bbl/hr. Lost 15,411 bbls 3% KCL and 669 bbls sized salt pill total. Avg losses to well 24 hrs= 22 bbls/hr. J-bsk recovery Daily= 0#Total = 893#. Ditch &String magnets Daily= 0# Total = 15354. Scrap iron out of WP Non intact Tbg or blast Jt Daily =0#total = 0#. Tbg/ Blast jt intact Daily= 0 Total = 1,228.94'. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-02 50-733-10056-00 166-049 11/3/14 12/5/14 Daily Operations: 12/04/14-Thursday RIH w/ESP on 2-7/8"tbg to 5,730'. Installing cannon clamps on every jt and testing cable every 1,000'. PU GLM, BX Nipple, and Dual string packer. Measure control lines and connect to packer. Cut cable and make splice to packer penetrator. Put safety valve in tbg while making splice. Finish splice and test same.Tested good. PU SSSV and tie in control line. Pressure up on SSSV and it opened at 1,700 psi.Test line for 5 min. RIH picking up 2 singles and 2 stands out of the derrick installing cannon clamps. PU landing jt.Tighten pups and put floor valve in top. MU hanger and orientate V on same. Run control lines through hanger. Cut ESP cable and splice in penetrator. Finish making splice. Put penetrator into hanger and lock in place. Test cable and umbilical cord. Good test. Up wt = 85K dn wt= 80K. Land hanger and run in LDS.Test ESP again and it still tested good. Pack off hanger. ESP Btm depth = 6,052.98'. Used 6 Mtr. clamps+ 12 pump -clamps+ 1 long splice clamp + 6 Band clamps+ 191 Reg. cannon clamps. Drop bar and set packer. Seen packer shear at 800 psi. Continue pumping to 2,500 psi. Hold pressure for 15 min. Bleed off pressure & line up to pump down annulus. Pressure up to 1,500 psi to test casing, hold for 30 min &charted. Test good. While testing break down last two remaining jts of 2-7/8"tubing in derrick. R/D tongs& remove f/rig floor. L/D landing jt &set BPV. N/D BOP's. Pull mouse hole. Bleed dn Koomey. Remove bell nipple & chains f/stack. Remove Koomey lines & plug while breaking bolts on lower well head riser. M/U strong back to top of annular. P/U stack and Install 4x4s to gain access to top riser bolts. Remove same, leaving top & btm 4-bolted. Remove annular& rental double gate F/cellar. At report time, installing shorty double gate. Lost 15,740 bbls 3% KCL and 669 bbls sized salt pill total. Avg losses to well @ 20:00 hrs = 14 bbls/hr.J-bsk recovery Daily = 0#. Total = 893#. Ditch &String magnets Daily= 0#.Total = 1535#. Scrap iron out of WP. Non intact Tbg or blast Jt Daily = 0#.Total =0#.Tbg/ Blast jt intact Daily= 0 Total = 1,228.94'. 12/05/14- Friday Get annular back on dbl gate. PU stack and move over to side. Nipple dn and pull riser. Clean up hanger and penetrator. Test penetrator, and everything is still good. Prep control lines for flange on tree. PU tree and lower dn to wellhead room. MU tree. [Repair oil leak in ST-80].Test void to 5,000 psi for 15 min.Good test. MU choke on tree. Pull BPV and (stall TWC.Test tree to 5,000 psi for 10 Min. Good test. Pull TWC. Pump down bleed line to 3,000 psi and blow out shear sub. [Welder is measuring for flow line and production rigging up control lines.]. RU Pollard slickline lubricator and test to 2,000 psi. Open SSSV. RIH with 2" RB to 328' and recover bar. POH and lay down bar. Change tool to a 2-1/2" GS and RIH to the RHCP. Pull free and POH. It was tight through the SSSV but they worked it through. Lay down RHCP and tool. RD slickline. [Rebuild 4" standpipe valve while slicklinning.] Turn well over to production at 16:20 hrs. Set mousehole back in and Lay dn 3 stds of 5" DP out of derrick. Remove mousehole. Prep to skid rig. Move rig west to gain access to well A-31 then north over well A-32 Secure rig. While continuing to clean pits, replacing manual choke & house keeping. Lost 15,740 bbls 3% KCL and 669 bbls sized salt pill total to well. Rig Released @ 00:00 Hrs. THE STATE GOVERNOR SEAN PARNELL V-ro - o ` 1) A I as,ka CL avid G z s 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.271.7542 Ted Kramer SCANNED NOVO 7 2014, Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai D & E and Hemlock Oil Pools, Trading Bay St A-02 Sundry Number: 314-573 Dear Mr. Kramer: 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, Cathy P. oerster Chair DATED this &"d—ay of October, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 5 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVED OCT 23 201 �AOG�� 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Ij' Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate D , Pull Tubing D Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install ESP ED 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development E • Stratigraphic ❑ Service ❑ 166-049 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-10056-00 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 [D Trading Bay St A-02 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018731 Trading Bay Field / Middle Kenai D, Middle Kenai E & Hemlock Oil Pools - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): . 6,669 .6,448 1 • 6,461 6,236 N/A 6,292 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,023' 13-3/8" 1,023' 1,007' 3,090 psi 1,540 psi Intermediate Production 6,546' 9-5/8" 6,546' 6,335' 3,950 psi 2,570 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic j See Schematic 3-1/2" & 2-7/8" 9.2# N-80 & 6.4# N-80 6,092'& 5,813' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See Schematic 5,222' (MD) 5,036' (TVD) / 5,795' (MD) 5,595' (TVD) / 6,065' (MD) 5,858' (TVD) & 321' 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El - Exploratory ❑ Stratigraphic ❑ Development E] Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/5/2014 Oil E1 Gas ❑ WDSPL [I Suspended ❑ WINJ E]GINJ ElWAG ElAbandoned F]Commission 16. Verbal Approval: Date: Representative: GSTOR ElSPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer(a)-hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature Phone (907) 777-8420 Date 10/23/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Ltd Mechanical Integrity Test ❑ Location Clearance El C Other: 6c'r- ` ' f' ( Spacing Exception Required? Yes ❑ No Subsequent Form Required: - `-Y t1 `j APPROVED BY Approved by: 12 COMMISSIONER THE COMMISSION Date. -/b 7i/ ?92� r �� 'i Submit Form and Form 10-40 (Revised 10/2012) Apr c i n 2 months from the date of approval et ts; up s/ - 6 2u IIilcorp Alaska, LL, Well Prognosis Well: A-02 Date: 10/23/2014 Well Name: Monopod A-02 API Number: 50-733-10056-00 Current Status: Oil producer (Gas Lifted) Leg: N/A Estimated Start Date: 11/5/14 Rig: Monopod Rig #56 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 166-049 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: I Dan Marlowe (907) 283-1329 (0) Current Bottom Hole Pressure: 1,925 psi @ 5,915' (5,711' TVD) From 8/1/2009 Static Bottom hole Pressure survey with 117 days shut in time. Maximum Expected BHP: 1,925 psi @ 5,915' (5,711' TVD) (gradient at depth .351 psi/ft (TVD) Max. Anticipated Surface Pressure: 1353 psi. (Using a .1 psi/ft. pressure gradient.) Brief Well Summary The A-02 well is currently is currently completed as a dual gas lifted oil well. The re -completion plan involves pulling the existing completion clean out well to the PBTD of 6,461'. The well will then be re -perforated in the D and E zones and the C zones will be added.. A new ESP completion will then be ran. , Brief Procedure: 1. MIRU Monopod Platform Rig # 56. 2. RU slickline. RIH on Long String with GR to see how deep of a cut we can make (Note: Schematic shows obstruction at 5,201'. 2012 WSR shows SL made it to 5,302 with a 2.82" GR ). RIH on SS side with GR. 3. RU E -line. RIH on Long String and Short string. Make cuts below packer at 5,222'. RD E -line. 4. Circulate Hydrocarbon off of well with 3% KCL. 5. ND Wellhead, NU dual BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 6. Unseat packer at 5,222' with 40k # over pull. Pull packer and production tubing out of well. 7. PU Work string. Repeat making cuts on production tubing and removing same to get to Packer # 2 @ 5,795'. Make cut in LS below packer. 8. PU burn shoe on Work string, RIH and burn over packer. POH and pick up O/S on Work string. RIH and retrieve Baker Mpodel F perm packer. 9. PU 2-7/8" O/S, RIH and catch production tubing at 5,800' 10. RU E -line. RIH with jet cutt4er and cut tubing string at 6,060' +/-. 5,410'(+/-). RD E -line. POOH with Production tubing. 11. PU burn Shoe. RIH and burn over Packer # 3 at 6,065'. POOH With shoe. 12. PU RIH with O/S. Latch packer and remove same. 13. PU RIH with 9-5/8" Clean out assembly and C/O well to PBTD of 6,461'. Pooh with Clean out Assembly. 14. RU E -line. RIH with GR/CCL and log well from PBTD up to 1,020'. Send Log to town in both .pdf and .las format for final perf adjustments. 15. PU RIH with Test Packer to 4,700 ft. Set packer and pressure test casing to 1,500 psi for 30 minutes. Charting same. �sfi ? Well Prognosis StA Well: A-02 Hilcoro Alaska, i 3� �,�p_ Date: 10/23/2014 16. RD: and change well head to ESP. NU BOP and Re-test�j, Ste« TQc, ttE,4-p 17. PU RIH with TCP perforating guns spacing out as per Final approved Perforation Request Form. RU E-line. Run tie in log. Place guns on depth. Fire guns. 18. PU on guns and circulate out perf gas. Monitor well for 1 hr shooting fluid levels to determine fluid loss. Fluid loss should diminish over time. 19. Once well is stable, POOH with TCP guns. 20. PU and run ESP with High set packer. Place bottom of ESP at 6,100'. 21. ND BOPs, NU Wellhead and test. -� �s F_ �� / 22. Turn well over to production. C4,_J- /3r y � Attnrhmantc- 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Proposed Wellhead. UNOCAL® RKB to TBG Hngr = 36.40' Tree connection: Dual 3" 5,000# KB ELEV = 101' PBTD = 6,461' ANGLE thru INTERVAL = 12.7° A-2 Schm4-29-98 L _ t i Trading Bay Unit Well # A-2 Re -Completed 3/20/77 CASING AND TUBING DETAIL SIZE N'T GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surf 1,027' 9-5/8" 40 & 43.5 K-55 & N-80 8rd LT&C 8.755 Surf 6,546 Tubing: 3-1/2" Camco KBUG Mandrel, 5.50" OD D 3,437' 2.875 3-1/2" Cameo KBUG Mandrel, 5.50" OD LS 3-1/2" 9.3 N-80 Butt. 2.992 0' 354' 2-7/8" 6.4 N-80 Butt 2.441 355' 6,092' SS 3-1/2" 9.3 N-80 Butt. 2.992 0' 5,301' 2-7/8" 64 N-80 Butt 2 441 5 301' 5 F.131 K 5,266' JEWELRY DETAIL 3-1/2" Otis "XA" Sliding Sleeve Closed L 5,301' NO. Denth ID UPM 5,363' 2.441 Blast Joints, 2-7/8", 3.688 OD, 50.23'lon FISH 14" Stip gun w/ bull nose @ 6292' 9/30/94 FILL LS Tagged obstruction w/ 1.9" GR @ 5201' 1/4/04 SS Tagged obstruction @ 5677' 12/8/94 PERFORATION DATA 36.40 Cameron DCB Dual 3-1/2" Tubing hangers, ._.Date Zone SHORT STRING A 321' 1.50 3-1/2" Otis Ball Valve, SSSV, 2.75 B 2,076' 2.875 3-1/2" Camco KBUG Mandrel, 5.56' OD C 2,972' 2.875 3-1/2" Camco KBUG Mandrel, 5.50" OD D 3,437' 2.875 3-1/2" Cameo KBUG Mandrel, 5.50" OD E 4,308' 2.875 3-1/2" Camco K13UG Mandrel, 5.50" OD F 4,773' 2.875 3-1/2" Cameo KBUG Mandrel, 5.50" OD G 5,149' 2.875 3-1/2" Cameo KBUG Mandrel, 5.50" OD H 5,187' 2.75 3-1/2" Otis "XA" Sliding Sleeve Closed 1 5,222' 5,500' Baker Pkr. Model A-5 Dual w/ 40,000# shear rel. w/ LHS conn. J 5,232' 3.00 Telescoping Swivel Sub (closed), 4.5" OD K 5,266' 2.75 3-1/2" Otis "XA" Sliding Sleeve Closed L 5,301' 2.441 Crossover, 3-1/2" X 2-7/8" Butt. M 5,363' 2.441 Blast Joints, 2-7/8", 3.688 OD, 50.23'lon N 5,596' 2.441 Blast Joints, 2-7/8", 3.688 OD, 71.04'lon 0 5,728' 2.313 3-1/2" Otis "XA" Sliding Sleeve Oen on 3/20/77) P 5,762' 2.205 Otis "XN' Profile Nipple, Tbg Plug set on 3/19/77 Q5,794' btm 5,814' 3/16/77Reperf Baker Parallel Flow Head w/ Baker Locator seal assembly E 58-1) 5,820' 5,825' LONG STRING 1 321' 1.50 3-1/2" Otis Ball Valve, SSSV, 2.75 2 354 2.441 Crossover, 3-1/2" X 2-7/8" Butt. 3 2,077' 2.875 3-1/2" Camco KBUG Mandrel, 5.50" OD 4 3,067' 2.875 3-1/2" Camco KBUG Mandrel, 5.50" OD 5 3,872' 2.875 3-1/2" Camco KBUG Mandrel, 5.50" OD 6 4,554' 2.875 3-1/2" Cameo KBUG Mandrel, 5.50" OD 7 5,148' 2.875 3-1/2" Camco KBUG Mandrel, 5.50" OD 8 5,185' 2.313 3-1/2" Otis "XA" Sliding Sleeve Closed 9 - 5,222' 30' Baker Pkr. Model A-5 Dual w/ 40,000# shear rel. w/ LHS conn. 10 5,365' 2.441 Blast Joints, 2-7/8", 3.688 OD, 50.31'lon 11 5,597' 2.441 Blast Joints, 2-7/8", 3.688 OD, 70.68' Ion 12 5,762' 2.313 3-1/2" Otis "XA" Sliding Sleeve Closed 13 5,795' 10/19/94 Baker Parallel Flow Head w/ Baker Locator seal assembly 4 5,795' 6.00 Baker Model "F" Perm. Packer, 190-60. 15 5,814' 2.313 3-1/2" Otis "XA" Sliding Sleeve Oen on 1/92 16 5,818' 2.441 Blast Joints, 2-7/8", 3.688 OD, 221.19' long 17 6,040' 2.313 3-1/2" Otis "XA" Sliding Sleeve Closed 18 6,059' Locator Seal Assy. 21.20' Ion 6,065' 3.25 Baker Model "D" 190-32 Retainer Production Pkr. 20 6,091' 2205. Otis ")CV' Profile Nipple 21 btm 6,092' 3,00 _ Mule Shoe FISH 14" Stip gun w/ bull nose @ 6292' 9/30/94 FILL LS Tagged obstruction w/ 1.9" GR @ 5201' 1/4/04 SS Tagged obstruction @ 5677' 12/8/94 PERFORATION DATA REVISED: 12/5/97 DRAWN BY: SLT _.._;Acc'um._. ._.Date Zone Top Btm Amt. SPF Last Opr. Present Condition 5,288' 5,290' 2' 2/14/77 Squeeze Perfs 53-8 5,400' 5,410' 10' 3/14/77 Cmt sq z'd off gas 53-8 5,410' 5,430' 20' 8 & 10 3/16/77 Reperf'd Open f/ Prod. 54-5 5,450' 5,480' 30' 1D 3/16/77 Rep erf'd Open f/ Prod. 54-9 5,500' 5,532' 32' 8 3/11/77 Rep erf'd Open f/ Prod. 5,590' 5,592' 2' 2/15/77 Squeeze Perfs 56-1 5,630' 5,640' 10' 8 3/12/77 Reperf'd Open f/ Prod. 56-1 5,660' 5,693' 33 8 3/12/77 Reperf d Openf/ Prod. 57-2 5,730' 5,785' 55 8 & 12 3/16/77Reperf d_Openf/ Prod. E 58-1) 5,820' 5,825' 5' i 2/12/77 sqz d off gas E 58-1) 5,826 5,850' 25 j 4 11/26/66 �Cmt 1 Isolated w_/ pkrs. Open f/ Prod. on LS. E (58-7) 5,900' 6,960' 60' 4 _... 11/26/66 r Isolated w/ pkrs. Open f/ Prod. on LS. E (60-0) 5,990' 6,020' 30' 4 1V 26/66 Isolated w/ pkrs Open f/ Prod on LS j Hemlock 6,090' 6,092' 2' 11/29/66 Squeeze Perfs Hemlock 1 6,110' 1 6,140' 30' 8 10/19/94 ,Open f/Prod. 6,149' 1 6,150' 1' 4 10/19/94 Erroneously perf'd Hemlock 6,150' 6,285' 136 8 10/19/94 Open f/ Prod. Heock ml 6,300' 6,420' 120' 4 11129/66 Openf/ Prod. REVISED: 12/5/97 DRAWN BY: SLT RKB to TBG Hngr = 36.40' CZN 47-5 CZN 48-5 CZN 50-0 CZN 50-3 CZN 50-6 CZN 51-0 CZN 51-6 DZN 53-0 DZN53-8 DZN 54-5 DZN 54-9 DZN 55-7 DZN56-1 DZN 57-2 EZN 58-1 EZN 58-7 EZN 60-0 Hemlock KB ELEV =101' PBTD = 6,461' ANGLE thru INTERVAL = 12.7° PROPOSED Trading Bay Unit Well # A-2 Completed: FUTURE CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surf. 1,023' 9-5/8" 40 & 43.5 K-55 & N-80 8rd LT&C 8.755 Surf 6,546' Tubing: SSSV 2 ±325' Packer 2-7/8" 6.5 L-80 8rd EUE 4 ±6,000' JEWELRY DETAIL NO. Depth ID Item Perforation Details 37.90 6.184 10" TBG Hanger Zone Top (MD) Btm (MD) 1 ±305' SSSV 2 ±325' Packer 3 ±340' X -Nipple 4 ±355' GLM 5 E ±6,100' Bottom of ESP Updated by: JILL 10/23/14 Perforation Details Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amount Condition CZN 47-5 ±4,738' ±4,767' ±4,566' ±4,594' ±29' Future CZN 48-5 ±4,833' ±4,839' ±4,658' ±4,664' ±6' Future CZN 50-0 ±4,996' ±5,010' ±4,816' ±4,829' ±14' Future CZN 50-3 ±5,022' ±5,048' ±4,841' ±4,866' ±26' Future CZN 50-6 ±5,088' ±5,100' ±4,905' ±4,917' ±12' Future CZN 51-0 ±5,132' ±5,142' ±4,948' ±4,958' ±10' Future CZN 51-6 ±5,161' ±5,223' ±4,976' ±5,037' ±62' Future 5,288' 5,290' 5,100' 5,102' 2' Sqz Perfs DZN 53-0 ±5,298' ±5,328' ±5,110' ±5,139' ±30' Future DZN 53-0 ±5,360' ±5,379' ±5,170' ±5,189' ±19' Future DZN 53-8 ±5,386' ±5,434' ±5,196' ±5,242' ±48' Future DZN 53-8 5,400' 5,410' 5,209' 5,219' 10' Cmt sgz'd off gas DZN 53-8 5,410' 5,430' 5,219' 5,239' 20' Reperf'd Open f/Prod DZN 54-5 5,450' 5,480' 5,258' 5,287' 30' Reperf'd Open f/Prod DZN 54-5 ±5,457' ±5,478' ±5,265' ±5,285' ±21' Future DZN 54-9 ±5,494' ±5,538' ±5,301' ±5,344' ±44' Future DZN 54-9 5,500' 5,532' 5,307' 5,338' 32' ReperPd Open f/Prod DZN 55-7 ±5,562' ±5,594' ±5,367' ±5,398' ±32' Future 5,590' 5,592' 5,395' 5,397' 2' 1 Sqz Perfs DZN 56-1 ±5,611' ±5,698' ±5,415' ±5,500' ±87' Future DZN 56-1 5,630' 5,640' 5,434' 1 5,443' 10' Reperf'd Open f/Prod DZN 56-1 5,660' 5,693' 5,463' 5,495' 33' Reperf'd Open f/Prod DZN 57-2 ±5,728' ±5,792' ±5,529' ±5,592' ±64' Future DZN 57-2 5,730' 5,785' 5,531' 5,585' 55' Reperf'd Open f/Prod EZN 58-1 ±5,816' ±5,858' ±5,615' ±5,656' ±42' Future EZN 58-1 5,820' 5,825' 5,619' 5,624' 5' Cmt sgz'd off gas EZN 58-1 5,825' 5,850' 5,624' 5,648' 25' Open f/Prod EZN 58-7 ±5,872' ±5,964' ±5,670' ±5,760' ±92' Future EZN 58-7 5,900' 5,960' 5,697' 5,756' 60' Open f/Prod EZN 60-0 ±5,986' ±6,007' ±5,781' ±5,802' ±21' Future EZN 60-0 5,990' 6,020' 5,785' 5,814' 30' Open f/Prod Hemlock 6,090' 6,092' 5,883' 5,885' 2' Sqz Perfs Hemlock 6,110' 6,140' 5,903' 5,932' 30' Open f/Prod Hemlock ±6,110' ±6,420' ±5,903' ±6,209' ±310' Future 6,149' 6,150' 5,941' 5,942' 1' Erroneously perf'd Hemlock 6,150' 6,285' 5,942' 6,075' 135' Open f/Prod Hemlock 6,300' 6,420' 6,090' 6,209' 120' Open f/Prod Updated by: JILL 10/23/14 Hilrnrp Alarka, MA; Monopod Platform A-2 133/8X95/8X31/2X 31/2 Valve, Safety, Willis C-20, 21/165M FE Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 SM SSO, X -bottom prep Casing head, Shaffer KD, 135/83MX 13 3/8 SOW, w/ 2- 2" LPO, Monopod Platform A-2 Current 10/22/2014 Tubing hanger, dual, CIW- DCB, 11 5M X 3 Y2 EUE 8rd lift X 3 Y: IBT bottom, w/ 3" type H BPV profile, 1/8 non cont control line ports in hangers Tree assy, dual block, CIW-F, 115MX31/85MX 3 1/8 5M, prepped on 5 3/64 center, 3" CIW seal pockets, % npt control line exits Willis C-20, 5M FE IW -F, 2 1/16 5M FE, HWO, AA CIW ball valve Hiilmrp Alnoka, LIA. Monopod Platform A-2 133/8X95/8X27/8 Valve, swab, W 3 1/8 5M FE, F T-24 Valve, wing, WKM-M, 2 1/165M FE, HWO, T-24 Valve, lower master, WKM- 3 1/8 5M FE, HWO, T-24 Tubing head, CIW-D 135/83MX11SIM, 2- 2 1/16 5M SSC X bottom Casing head, Shaffer KD, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2" LPO, Monopod Platform A-2 Proposed ESP 10/22/2014 Tubing hanger, CIW-DCB-ESP, 11 X 3 % EUE lift and susp, w/ 3" type H BPV profile, 5'/. EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator BHTA, Bowen, 3 1/8 5M FE X 3" Bowen Quick Union VKM-M, 3 1/8 5M FE, w/ MA -16 operator .oadstool, 11 5M I FE, prepped for -'/� npt continuous ine ports WKM-M, 2 1/16 5M FE, HWO, DD CIW ball valve Hilv"rp Aln.kr, LII: It -H Monopod Platform 2014 BOP Stack (A-2) 10/23/2014 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: April 5, 2001 FROM: Jeff JOnes, ~ SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field Thum. d~.y, Apri! .$, 200t :1 traveled to UNOCAL's Monopod Platform and witnessed the semi annual safety valve system testing. Lead operator Gary Smith conducted the testing today; he did a thorough job and was a pleasure to work with. As the AOGCC Safety Valve System test report indicates i witneSsed the testing of 18 wells and 53 components, with four failures: The pilot on well A-02 tripped at 26 psi and was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed. I indicated to Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 $SSV failed to close and will require maintenance. Wells A-13 and A-21 have been certified as "no flow" status and do not have SSSV's installed. While on location i inSpected the platform and found it very clean and it appeared to be in excellent condition. Summary: I witnessed the semi annual Safety Valve System testing at Unocal's Monopod Platform in the Trading Bay Field. Monopod Platform, 18 wells, 53 components. 4 failures, 7.5% failure rate. Platform inspection conducted. Attachment: SVS TBF Monopod Platform 4/5/01 JJ NqN-CONFIDENT,.!A.L. SVS TBF Monopod Platform 4-5-01 J~l Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: UNOCAL Operator Rep: Gary Smith AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Date: Field/Unit/Pad: Trading Bay Field Monopod Separator psi: LPS 65 HPS 4/5/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE :A-01RD 1901470 65i 45 42 P P P OIL ~A~t}2.~ '" ~'1660490 '65 45 26 3 P ~'43' 4/5/01 OIL A-03RD3' ~ 1971300 65! 45 42 P P P ''OIL A-04 1670020 A-06 1670250 651 45 45 P P ~43 oIL A-07 1670460 ~5~! 45 42 P P P OIL , , A-09RD 1810360 A-10 1670760 iA. il 1700240 65 45 43 P P '~r43 'OiL A-13 1680020 65 45 41 P P OIL ,, A- 14 1680270 !A-15' "i68033'0 65 45 45 P P P 'OiL A-16RD 1880380 65 45 41/42 P P P OIL [A-I'7RD 1810670 65 45 43 P P P ' 'oiL !A-18 1680760 6~' " ~5 47 P P i' ' OIL A'21 1700470 65 45 46 P P OIL .... ,, ,, ,, A-22 1700310 65 45 44' P P P OIL A-23 1700590 ' ' , , , , , , A-23DPN 1720200 A-24RD 1810400' 65 45 4'1 P P P " oIL iA-27RD1 1970630 ' ' 65 45 43 P P e OIL A-28RD 1890920 ' 65 45 45 ' P P P "OIL A-30 1730140 ' ' ' A-32 1770180 65 45 44 P P P 'OIL , , ,, Wells: 18 Components: 53 Failures: .... 4 Failure Rate: 7.5% F1 o0 var Remarks: A- 13 & A-21 reported as No-Flow wells. SSSV's removed for repair: A-02 out since 2/24/00, A-11 out since 11/7/99. A.-02 pilot r.epaired and retested "OK". A-06 SSSV failed to close. A- 16 RD is a dual completion. Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 November 22, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: ~(..~ --- ~ On October 19, 1994 the following intervals were perforated in well A-2 (API 50-733-10056-00) on the Monopod platform in Trading Bay Field: BENCH TOP (MD) BOTTOM {MD) FEET Hemlock 6110 6140 30 Hemlock 6150 6285 135 TOTAL 165 S ince~~,~~ STATE OF ALASKA -~ ALA?'-"~ OIL AND GAS CONSERVATION ')MMISSION REPOh I' OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate X_ Pull tubing . Alter casing Repair well Pull tubing m Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1613' N, 570' W of SE Cor., Sec. 4, T9N, R13W, SM At top of productive interval 387' N, 1352' W of Surface Location At effective depth At total depth 456' N, 1463' W of Surface Location 5. Type of Well: Development X_ Exploratory __ Slmtigraphic __ 6. Datum elevation (DF or KB) KB: 112' 7. Unit or Property name Trading Bay Field 8. Well number A-2 feet 9. Permit number/approval number 66 -0049 -0 10. APl number 50-733-10056 -00 11. Field/Pool Trading Bay/Hemlock, Tyonek 12. Present well condition summary Total depth: measured 6669 true vertical 6448 feet Plugs (measured) feet Effective depth: measured 6461 true vertical 6236 feet Junk (measured) feet Casing Length Structural Conductor Surface 1023' Intermediate Production 6546' Uner Perforation depth: measured true vertical Size Cemented Measured depth True vertical depth 13-3/8' 950 sx 1023' 1007' 9-5/8' 1150 sx 6546' 6335' 5400-5430, 5450-5480, 5500-5532, 5623-5693, 5730-5785, 5820-5850, 5900-5960, 5990-6020, 6110-6140, 6150-6285, 6300-6420 5210-5239, 5258-5287, 5307-5338, 5427-5495, 5531-5585, 5619-5649, 5698-5756, 5786-5815, 5903-5933, 5943-6076, 6091-6209 13. Stimulation or cement squeeze summary 14. Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, N-80 & 2-7/8", 6.4#, N-80 @ 6092' SS: 3-1/2", 9.2#, N-80 & 2-7/8', 6.4#, N-80 @ 5814' Packers and SSSV (type and measured depth) Baker 'A5" @ 5222'; Baker "Fl' @ 5796'; Baker 'D" @ 6059' Otis BV @ 320' _., · ,.- ~'~ RE£tlv ,u Intervals treated (measured) Treatment description Including volumes used and final pressure Representative Daily Average Production or Inlecfion DataNIC,~iat ~ APR 2 0 1995 Nsska Oil & 6as Cons. Commission Prior to well operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 235 533 464 720 Tubing Pressure 85 Subsequent to operation 285 578 426 740 130 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil X_ Gas __ Suspended Service Signed ~ ~ Form 10-404 Rev 06/15/88 correct to the best of my knowledge. SUBMIT IN DUPLICATE Oil & Gas Division Unocal Corporation ~... P.O. Box 190247 Anchorage, Alaska 9951~. -;7 Telephone (907) 276-7600 UNOCAL ) Alaska Region Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 August 24, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well A-2 (API# 50-733-10056-00) on the Monopod platform. BENCH TOP (MD) BOTI'OM, (MD) FEET Hemlock 6110 6140 30 Hemlock 6150 6285 !35 TOTAL 165 RECEIVED SEP - ? 1994 Ataska 0il & Sas Cons. Commission Anchorage i'. Type of request: Abandon __, · ~_ ~,end __ Operalions shutdown__ Re-ent~ .depended wellm Alter casing__ Repair well m Plugging ~ Time extenelon ~ Stimulate __ Char.ge approved program Pull tubing Variance Perforate X_ Other__ 2. Name of Operator 5. TyPe of Well: 6. Datum elevation (DF or KB) Unocal ~ X_ KB: 112' ~ __ feet 3. Address stmtigraph~ m 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 sense __ Trading Bay Field 4. Location of well at surface 8. Well number 1613' N, 570' W of SE Cor., Sec. 4, T9N, R13W, SM A-2 387' N, 1352' W of Surface Location 66-0049-0 At effective depth Slip - 7 ~994 10. APInumber 50-733-10056-00 At total depth AlaSka U~I & Sas Cons. Commission 11. Field/Pool 456' N, 1463' W of Surface Location Anchorage Trading Bay/Hemlock, Tyonek 121 Present well condition summary Total depth: measured 6669 feet Plugs (measured) true vertical 6448 feet ORIGINAL true vertical 6236 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1023' 13-3/8' 950 sx 1023' 1007' Intermediate Production 6546' 9-5/8' 1150 sx 6546' 6335' Liner Perforation depth: measured 5400-5430, 5450-5480, 5500-5532, 5623-5693, 5730-5785, 5820-5850, 5900-5960, 5990-6020, 6110-6140, 6150-6285, 6300-6420 true vertical 5210-5239, 5258-5287, 5307-5338, 5427-5495, 5531-5585, 5619-5649, 5698-5756, 5786-5815, 5903-5933, 5943-6076, 6091-6209 Tubing (size, grade, and measured depth) LS: 3-1/2', 9.2#, N-80 & 2-7/8', 6.4#, N-80 @ 6092' SS: 3-1/2', 9.2#, N-80 & 2-7/8', 6.4#, N-80 @ 5814' Packers and SSSV (type and measured depth) Baker 'A5' @ 5222'; Baker 'Fl' @ 5796'; Baker 'D' @ 6059' Otis BV's @ 320' 13. Attachments Description summary of proposal X_ Detailed operations prograrn~__ BOP sketch _ Questions? Call John Paul McKee @ 263-7680 or Ralph Holman @ 263-7838 14. Estimated date for commencing operation !5. Status of well classtrCation as: September 10, 1994 161 If proposal was verbally approved Oil X_ Gas ~ Suspended ~ Name of approver Date approved Service 17. I herr~e_by ce[ti1 ~regoing is true and correct to the b~.st of my knowledge. FOR coaa~sg~N usE eNL./ ConU on.. of p,'ov-ai Com, on .,o ""W I App,'ov,, _No. Plug Integrity _ BOP Test_ Location clearance _I ~,~r ~_ ,~ ¥ [ Mechanical Integrity Te~__ Subsequent form required 10- ~ ~ Original Signeu ~- Approved by the order of the Commission David W. Johnston Commissioner Date .~//~"/'~ ~( Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Approved Copy Returned August 27, 1994 Mono_m>d Platform, Wel! A4 Perforating Procedure 1. Hold safety meeting. 2. Rig up electric line unit. 3~ . Pressure test lubricator to 2500 psi for five minutes. Note: A pump-in sub with a valve is required. Shut down all welding and radio transmissions. 5. Run in hole and perforate intervals as instructed by Unocal wimess. (When gun is 200' below surface, welding and radio transmissions may resume.) 6~ Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL FEET Hemlock 6110-6140 30 Hemlock 6150-6285 135 TOTAL: 165 RECEIVED SEP - 7 1994 Alaska Oil & Gas Cons. Commission Atlohorage 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, RGea~~onS~~~l ~rS~.h~ 1~ in~~ ~an~ager GSB/lew CONDUCTOR 1 2 3 4 5 6 7 8 9 l0 ll 12 13 14 15 16 17 18 19 20, 21 22 24 25 26 27 28 29 30 31 32 MONOPOD CENTER FROM SOUTHEAST CORNER, SECTION 4, TgN, "Y" = 2,523,126 LAT. 60053, 48.65 "X" = 218,871 LONG.- 151o34, 43.51"' ~/,~ "Y" COORD. "X" COORD. 2,523,134.3 218,880.9 2,523,130.2 218,883.2 2,523,125.7 218,883.9 2,523,121.7 218,883.2 2,523,118.2 218,881.3 2,523,114.4 218,876.8 2,523,113.2 218,873.0 2,523,113.2 218,869.0 2,523,114.8 218,864.6 2,523,117.7 218,861.1 2,523,121.8 218,858.8 2,523,126.4 218,858.1 2,523,130.3 218,858.8 2,523,133.8 218,860.7 2,523,137.6 218,865.2 2,523,138.8 · 218,869.0 2,523,138.8 218,873.0 2,523,137,.2 218,877.4 2,523,132.8 218,875.7 2,523,129.4 218,878.6 2,523,132.0 218,870.8 2,523,128.4 218,873.9 .,.2,523._?_.a.8.-_~ --__ .~.?.'l~t. R7K. CJ 2,523,133.9 218,867.0 2,523',120.9 218,878.1 2,523,131.4 218,863.9 ' 2~523,118.1 .218,875.0 2 ~j 523,127.2 218,865.1 2~523,123.6 218,868.1 2;~523,120.0 218,871.1 2,.523,122.6 218,863.4 2.1523,119.2 218,866.3 WELL # A-28 A-25 A-30 A-27 A-23 A-21 A-22 A-14 A-13 A-17 A-8 A-15 and RD FSL FEL 1621 554 1617 551 1612 551 1608 551 1605 '553 , 1601 557 1600 561 1600 565 1601 570 1604 573 1608 576 1612 577 1616 577 1620 574 1624 570 1625 566 1625 1624 1619 1616 1618 1615 1611 1600 1607 A-24 and RD A-29 A-9 and RD A-19 A-18 A-II A-3 ,, A-1 A-7 A-4 A-6 A-32 562 558 559 556 564 561 55.P "568 556 A-12 and RD 1617 571 A-20 1604 559 A-2 16!3 57O A-16 1610 566 A-26 1606 563 A-10 16Q9 571 A-5 and RD 1605 568 1 &2 U!IIUII UII L_,UIIIJ, J[::Jlly LI l,_,ulllUIIIl(.~ ! :) O. Box 6247, Anchorage, Alaska ggs02 'J ~;lephone: (gO7') 276-'?600 uni: n November 15, 1977 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE' TBS(A-~,2~ A-18, A-16 A-4,-~--13 MONOPOD PLATFORM Dear Mr. G lbreth' Enclosed for your files are two (2) copies of the completed Well Histories for the above captioned projects. Sincerely yours, ,L ~.~:~,.~.~._~.. (Jim'R") Cal lender D~i sty.~ Drl g. Supt. cc' Marathon Oil Co. USGS Harry .Lee RECEIVED NOV ~'~ 1911 inn OJ OJl & J~;.i~ g.,,~;vf.~llon .... T .111_ III Il, [ : I [ D-,J,,-, UNIO,_., OIL CO. OF CALIFOF,,.,ilA SHEET A REPAIR RECORD PAGE NO, LEASE FIELD Trading Bay Field TYPE UNIT__ 3EGAN: 2/4/77 COMPLETED: 2/22/77 ELEVATIONS: ~ERMIT NO. 66-r~9 SERIAL NO. ADL-18731 ~OMPANY ENGI/iN~ER .~ W~3tson/Chr~iswell ; ' ~ ..... 1' ~ .... (./ ...... ~,~um- CASING & TUBING RECORD Trading Bay State WELL NO. A-2 CONTRACTOR_ Parker Drilling Co. Oi!we!! GROUND Wtr. depth 62' MLLW CASING HEAD TUBING HEAD RT-Oce,n l*!rm~' 174' ROTARY DRIVE BUSHING RT MSL !Ol' ...... 'SIZE DEPT~ _ . . WEIGHT GRADE ......................... REMARK~ '" 13 3/~ 1023' 61# K-55 Butl. Cmt'd w/950 sx. Construction Cmt. mixed w/ sea wtr. 9 5/1 6546' 40#,43.5# N-80 But~. Cmt'd 1st stage 6546'-3903' w/l150 sx mixed w/ sea wtr. & 2nd ,stg. 3903'-1200' w/1080 sx mixed w/ sea wtr. 3 1/2 & 2 7/8 @ 6092' N-80 Long String. 3 1/2 & 2 7/8 @ 5796' N-80 Short String. · , PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION i l-26-~6 5820'-5850' 6461' Open for Production. " 5900'-5960' 6461' " " " " 5990'-6020' 6461' " " " l 1-29-( 6 6110'-6140' 6461' " " " " 6150'-6285' 6461' ,i ,, ,, ,, 6300'-6420' 6461' " " " 6090'-6092' 6461' Sqz. fgr Bend Sqz. for bond w/ 20 sx. cmt. @ 3600 psi. 2/13/7i? 5780'-5785' 5875'BP Sqz for Iso] Sqz. dwn. 350 sx. Class "G" cmt. 2/14/77 5288'-5290' 5360' " Sqz. w/ 28 sx. Class '"G'" cmt. 2/15/717 5590'-5592' 5536' ,, Open for Production. · 2/19/77 5730'-5785' 6461' Open for Production. 5623'-5693' . 6461' . Open for Production. INITIAL PRODUCTI¢ AIR DATE [ INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE: MCF 4/3/77 "D" & Hemtoc[~ 1205 4 1% 31.7° 185 107 7737 6420 flowing from btm. strings. I · . WELL HISTORY PRIOR TO REPAIR LAST COMPLETION NO. ;OMPLETION DATE: 12/8/66 ~RODUCING INTERVAL: 5820 '-6420' NITIAL PRODUCTION: zt ~ ,-,~,~.~/~ ~..~+~ ~,~ ~/~ ~-~ *~- ~-~ ~- ,AST REGULAR PROD. & DATE: 1/31/75 136/136 B/D, 0.3% cut Hemlock only. ;UMULATIVE PRODUCTION:. 973,233 bbls. Hemlock! IEASON FOR REPAIR: To fracture stimulate the Hemlock ~orm D-IOO1-B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO. Ii 2 LEASE Trading Bay State COMPLETION DATE: 2/22/77 DATE DATE 2/19/77 2/19/77 2/19/77 TYPE: E.T.D. INTERVAL 5500'-5532' 5450'-5480' 5400'-5430' WELL NO. A-2 FIELD Tr_~_d~,~g m_~_y Field APPROVED .l'im R DETAILS 'OF OPERATIONS, DESCRIPTIONS & RESULTS ETD REASON PERFORATING RECORD (continued) PRESENT CONDITION 6461' Open for Production Il II I1 II ti I1 II II Shaffer/Cameron WELL I~EAD ASSEMBLY CASING HEAD: Shaffer 12" 3000# slip on weld CASING HANGER: 12" 3000# 9 5/8" slip CASING SPOOL: TUBING HEAD: Cameron 10" 5000# X 12" 3000# DCB tbg. spool 3 1/2" Cameron dual Buttress. TUBING HANGER: TUBING HEAD TOP' 10" 5000# Cameron dual tree "F" Gate, dual stss. solid block, 10" 5000# w/ prep 1" control MASTER VALVES: line w/ 2 ea. 3 1/8" bo~ecmaster valves, 2 ea. 3 1/8" swab valves. 3 1/2" EUE CHRISTMAS TREE TOP CONN.: - · · . _ OIL :PNIY DF CALIF IIA I,,ELL Tradinq Bay State ~'~-l_k t~O, TBS A-2 FIELD Trading Bay Field ~TE 2/4/77 1 .2/5/77 2/6/77- · 2/7/77 2/8/77 2/9/77 ;2/10/77 2/11/77 2/12/77 .2/13/77 6669 'TD 6461 'ETD (fl. col 9 5/8" .csg@ 6546' Baker Mod A Hyd. duatp @4585' Baker Mod E hyd. sing]l e pkr. @6040' Same headi Same headi n . Same headin, .. 6669'TD 6461 'ETD fl oat collar. 9 5/8" csg. @6546' 6669'TD 6461 'ETD - float collal 9 5/8" csg. @6546' 6669'TD 5875'ETDBP 9 5/8" csg. 6546' Same heading Same heading I)ETAILS OF OPEPATIONS, I)ESCRIPTIOIIS & REStarTS Activated rig w/ partial crews from 12:01 a.m. 1/11/77 through' 6:00 p.m. 1/21/77. Recommenced activating rig 1'2:01 a.m. 2/3/77 w/ full R.U. crews. Moved rig over TBS A-2. Rigging up misc. equip. R.U. I~.L. to shift sleeve in long string. Shifting tool stopped @6003'. "XO" sleeve @6025'. Ran 2 3/16" Imp. Blk 2 7/8" csg. tbg. collapsed to 2" @ 6003'. Finished R.U. and mixed mud to kill TBS A-2. Commenced W.O. operations on TBS A-2 12'01 a.m. 2/5/77. Killed well w/ 68# Dril-S 5% KCL W.O. fluid..Circ, gas cut mud from 9 5/8" annulus. Communication between L.S. and S.S. between pkrs. S.S. in communication w/ annulus. Set W.L. plug in L.S. Nipple down X-mas tree R..U. BOE. Pulled S.S. clear of pkr. Tried to unseat pkr. w/ L.S. Ran free pt. Cut L.S. @4560'. Started laying down dual 2 7/8" tbg. strings. Tongs broke down at 10:30 p.m. Waited on parts. Pulled 2 7/8" dual tbg. string. Changed out power tongs four times. Layed dwn. 2 7/8" tbg. string. Made up fishing tools. RIH on 5" DP to 45.60' Caught fish Pooh. Left part in place @6036'. RIH w/ O.S. ~ 2 7/8" grappie. Worked top fish to 6121'. Pooh. RIH w/ 3 5/8" grapple Ran 7 5/8" O.S. Caught fish @ 6121'. Pooh. Left 18" junk tbg. in hole. RIH w/ 8 1/2" bit to 6461'. Pooh. RIH w/ bit & 9 5/8" csg.'scraper to 6461'. Circ. hole clean. Pooh. R.U.W.L. R.U. Schlumberger. Ran GR-CBL-Sig., CNL, and TDT logs. R.D. Schlumberger. Set BP @1059'. Changed tb§. spool. Cameron 22" 3000# X 10" 5000# and tested o.k. Set BP @5875~ 'RIH w/ 5" DP. Spotted 35 sx. sand @5865". Tagged sand @5870' Spotted 35 sx. sand, tagged top sand @5815'. Cleaned to 5825' Pooh. RIH w/ squeeze, tool. Mix. ed and pumped 200 sx. Class "G'" cmt. w/ .75% D-31, 0.3% D-19 an'd 0.1% D-6. Broke dwn. per.fs. @5820-5825' w/ 2500 psi. Max. squeeze press 4000 psi. Rev. out 90 cu.ft, cmt. Pooh. RIH w/ 8 1/2" bit & csg. scraper. Drilled cmt. from 5737'-5826' Circ. out sand to 5828' Pooh. RIH w/ cmt. ret. set @5796'. 'Press. perfs. @5820'-5828; to 3800 .psi. No breakdown. R.U. GO Int. Ran 5' gun. Found fill @5817'. Pulled gun. Pooh. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 5833'. Pooh. RIH w/ cmt. ret. set @5796'. Broke dwn. perfs. @5820-5833' (lO cfm @3000 psi). Pulled up. to 5300'. R.U. GO Int. Ran 5' 4 spf t.t. gun. Perfed 5780' to '5785'. Set ret. @5796'. Tested blank @ 5785'-5820' for isolation w/ 1000 psi diff. Held o.k. Pooh. ' ? SI IEET g Trading BaY State IJNIOtl OIL c0r,"£/vN OF CALIFOFCilA I CORD · . ~,~ELL I'D, TBS A-2 FIELD Trading Bay Field · . \TE ! 2/14/77 2/15/77 2/16/77 -. 2/17/77 4 2/18/77 2/19/77 6669'TD 5360' ETD retr. BP 9 5/8" csg@ 6546' ' 6669'TD 5536' ETD(crat : 9 .5/8". csg.: @6546' - 6669 'TD 6461 'ETD 9 5/8" csg csg. @6546" 6669'TD 6461'ETD ' 9 5/8" csg'@ 6546' · 6669'TD ' 6461'ETD 9 5/8" csg.@ 6546" Same heading DETAILS OF OPERATIONS, DESCRIPTIC~]S g RESULTS RIH w/ retr. head on 5" DP. Moved Bake~ retr. BP from 5880' and set @5360'. Spotted 25 sx. sand over BP. Tagged top sand @5308'. Pooh.' R.U. GO Int. RIH w/ 4" squeeze gun. Shot 5288'-5290', 4 hpf, R.D. GO Int. RIH w/ Baker retr. cmt. ret. set @5218'. Broke perfs @2600 psi (22 cfm @2400 psi). Mixed 150 sx. Class "G" cmt. w/ .75% D-31, 0.3% D-19~'0.1% D-6. Pumped 50 cf water cushion, 150 sx. cmt., 50 cf water. Pumped 150 sx. cmt. @bcfm w/ max. press. 3000 psi. S.I. 1 hr. Bled to 0 psi. Rec. 5 cf fluid. Pulled Baker retr. cmt. ret. to 5077'.- Rev. out 30 cf clean water, 20 cf water cut cmt. WOC. CIP 8:40 p.m. 12/14/77. Pooh. RIH w/ 8 1/2" bit & 9 5/8" csg. scrapem. Drilled cmt. 5225'-5300. Pump sand to 5355' Pooh. RIH Baker retr. tool. Circ. clean. Move retr. BP to 5670'. Spot 25 sx. sand. Top sand @5615'. Pooh. R.U. GO Int. Perf. 5590'-5592' w/ 4" squeeze gun,..4 hpf. RD GO Int. RIH w/ Baker retr. cmt. ret. set @5515'. Broke perfs. @5590'-5592' w/ 2600 psi @ 4 cfm. 2200 psi on ann. Mixed 50 sx. C1 "G" cmt. w/ 0.3% D-19, 0.1% D-6 .75%'D-31. 50 cu.ft, cushipn ahead & behind. Squeezed 22 sx. to perfs, 28 sx. outside. -Max. press. 2750 psi @ 5 cfm. SI 1 hr. Pulled tool to 5422'. Rev. out 40 cf water. No cmt. CIP 11'45 p.m. 2/15/77. Held 1800 psi on squeeze. WOC. _ · Bled press, off @ 3:00 a.m. Pooh w/ Baker retr. cmt. ret. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. Tagged cmt. @5536'. C.O. to 5602'. Pooh. RIH w/ retr. tool. P.U. retr. BP. Pooh. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 6461'. Pooh. RU GO .Int. Ran CBL-CNL-Collar log to 6461'. RD Go Int. Stand DP in derrick. Brought Dowell frac. equipment on deck. RU Dowell. RU Dowell to frac. Hemlock Zone. Mixed frac. fluid. RIH w/ retr. pkr. on 5" DP. Set pkr. above Hemlock Zone @6045' for frac. job on perfs. @6110'-6140', 6150'-6285', 6300'-6420'. Tested surface lines to 6000 psi. Tested pkr. and liner bond @ 2000 psi surface. Injected 48 bbls 12% HCL +3% HF +.4% Al30 + 7% U66. Close bypass and press, annulus to 700 psi.. Pump 124 bbls frac. fluid at 2600 psi. Injected 120 bbls 0.5 ppg sand @2800 psi at 15 BPM .. 288 bbls 1 ppg sand @2500 psi 264 bbls 2 ppg sand @ 3000 psi 216 bbls 3 ppg sand @3200 psi max. 375 bbls 4 ppg sand @3600 psi max. 72 bbls frac fluid @3800 psi max. Injected 55 bbls frac. fluid @ 5 BPM @4200 psi max. 5 min. SI 2900 psi lO min. SI 2450 psi 30 min. SI 1450 psi .Pooh w/ pkr. RIH w/ bit & csg. scraper. Clean sand from 6387'-6461'TD. Pooh. RU GO Int. Ran GR 6460'-5300'. Perforated D Zone sands in 8 runs, 5730' -5785' 5623' -5693' 5500' -5532', 5450' -5480' 5400' -5430 @ 4 hpf. RD GO Int. RIH w/ bit & scraper to 6461'. Pooh. RU GO Int. Ran junk basket & gauge ring to 6461'. No junk. Rill on W.L. Baker Model D 9 5/8" x 2 7/8" single perm. pkr set above Hemlock @6065' · '- '-~-;'J-- UNION OIL CQ ' PN Y CALIFORNIA -J~SE Tradinq Bay State i',F_LL t CORD · NO, "-' SHEET PAGE .. .o FIELD Trading Bay Field ~TE 6 2/20~77 7 2/21/77 2/22/77 .__ : . . _ .. -. ., -. . 2/24/77 . -:. . ).0 3/1/771 3-/2/77 DETAILS OF OPERATIONS, DESCRIPTIOtlS & RESULTS Same heading Same heading ._ · 6669'TD ' - 9 5/8" csg. @:-6546' : Baker dua, 1 . pkr @. 5276~ Baker Mod F dual perm' pkr @5796': Baker Mod D single perm. pkr. @606~I : 6669 'TD 5/8" csg~ ,6546' Baker Mod ~ dual perm.' pkr @5796' Baker Mod D single perm. pkr @606~': 6669 'TD ' 6461. 'ETD ' (fl. collar) 9 5/8" csg- @6546' · Baker A-5 h pkr @5246' ' Baker Mod F perm pkr @57 ' Baker Mod D RIH on W.L. Baker Mod E dual 9 5/8" x'2 7/8"x 3 1/2" perm. pkr."set'between D & E Zones @5796'. RD GO Int. Ran dual 2 7/8" x 3 1/2".tbg. str. w/ j~welry. Stabbed into Baker Mod D pkr. @6065'. Tested to 700 psi. Spaced out, landed tbg. Set Baker hyd. pkr. above D Zone perfs. 5238'.' Tested all 3 pkrs. to'700 psi above & below o.k. Removed POE. Installed X-mas tree. Tested ~to 5000 psi. Displaced mud w/ diesel between Baker Mod D & Mod .F & hydraulic pkrs. .. Displaced mud w/"salt water above dual-..hydraulic pkr. RIH w/ W.L- to set BV in. L.S. Unable to get BV to latch due to X over directly below BV mandrel.' Tri State made 2 7/8" K'valve X Over to BV dummy. RIH w/. K valve. Set press._@ 50 psi tbg. S.S. BV in plac~ - ._ _ . . Moved rig off TBS A;2 to.TBS A-18 12'00 midnite 2/22/77 A-2L 2/24/77 (.last 12 hr. aver'age) Gross Cut Net GOR GLR Gray. 733 16% 616 2588 3202 32.4 Tbg/csg. Press 610/913 A-2S 2/24/77 (last 2 hr average) Gross Cut Net GOR GLR Gray. 474 8% 437 ........ (SI due to sand cut bean.) Tbg/csg. press Recommenced WO activities on TBS A-2 at 12:01 a.m. 3/1/77. Killed' .L.S., S.S. & Annulus between Baker Mod F pkr. @5796' and Baker A-5 hyd. pkr @5246' w/ 5% KCL Dril-S WO fluid. Pumped dwn. S.S. thru XA sleeve at 5216' and circ. out gas cut mud in annulus above dual pkr at 5246'. Unable to release dual pkr at 5246'. RU GO Int. Ran free point to pkr at 5246' in S.S. tbg. Tbg. stuck at pkr. Cut S.S. above pkr at 5240'. perm. pkr @6 65' 6669'TD 6461 'ETD (fl. collar) 9 5/8" csg. @6546' Baker Mod F perm pkr @5796' Baker Mod D perm. pkr @6065' Cut 2 7/8" L.S. @5225', 21' above Baker A-5 dual hyd. pkr. set above D Zone @5246'. Pooh w/ 2 7/8" L.S. tbg. and layed dwn. same. RIH w/ Tri-State O.S., and jars on 5" DP. Engaged top of fish @5225'. Jarred fish loose. Circ. bottoms up. Pooh and layed dwn. Baker A-5 dual hyd.-pkr & dual tbg. strings hung below pkr. Found 2" diam. blast holes in both long and short strings @5664' (5649' DIL meas) opposite 56-1 sand perfs @5623' to 5693'. Recovered total fish, well clear of. tbg. S EET D AGF. I'JO,., 6 ASE .Trading BaS State UNIOf OIL CCr£NN OF. CALIF tIA ELL I CORD . ~LL ~JO, TBS A-16 F~ELD Trading Bay Field ~TE i 22 3/3/77 =)3 3/4/77 .)4 3/5/77 5 3/6/77 3/7/77 Same Headin Same Headin · Same Headin, Same Head~i n 6669 'TD 6461 'ETD - (fi. collar 9 5/8" csg. @6546'. Baker Mod' Fi hyd. pkr~ @5238' Baker Mod F perm. pkr w/ plug @5796' Sand plug 5796' - 5780' Baker Mod D perm. pkr @6065' DETAILS OF OPERATIONS, DESCRIPTIC~IS & RESULTS RIH w/ 700' 2 3/8" tbg. stinger on 5" DP. Washed sand opposite Hemlock perfs. @6275' to 6461'ETD. Pooh. RU GO Int. Logged 5795' to 5000' w/ CBL-VDL. RIH w/ Baker 6" latch plug for 9 5/8" Mod F'perm. pkr @5796' on W.L. Set plug in place. RD GO Int. Spot sand on top of same w/ 5" DP @5795' to 5780'. RIH w/ Baker 9 5/8" retr. BP on 5" DP set @5705'. Spot sand 5705' to 5660'. Pooh. RIH w/ Baker retr. squeeze tool Set @5547'. Broke dwn. 56-1 sand perfs (5623' to 5693') @2~00 psi, 3cfm @2600 .psi. Mixed 50 sx. Class'"G" cmt. w/ .75% D-31, .3% D-19 and .1% D-6. Used 50 cf water cushion ahead and behind cmt. Squeezed same @3cfm w/ 2600 psi. 21 cf to perfs. ISI 2800 psi,.'SI 5 min 1800 psi, SI lO min, 900 psi, SI 15 min. 0 psi. R~v. out 50 cf water.. CIP at 4:30 p.m. 3/4/77. WOC 8 hrs. RIH w/ bit & 9 5/8!' csg. scraper. Cleaned hard cmt. 5590' to 5595', stringers to 5660', top sand. PoOh. RIH w/ Baker retr. squeeze tool set @5547" Broke dwn. same sand w/ 2800 psi, 3 cfm @2600 psi. Moved tool to 5645', spotted 50 cf water on bottom. Reset tool @5547'. Mixed 100 sx., same mix Class "G" cmt. Used 50 cf water cushion ahead & behind cmt."~'Sq,ueezed @ 3 cfm w/ 3400 psi. 76'cf away. ISI 3400. Held 15 min. Rev. out 7 cf cmt.~ 50 Cf water. CIP 11'0'0 a.m. 3/5/77. Pooh w/ tool. WOC 7 hrs. RIH w/ bit and 9 5/8" csg. scraper. Drilled hard cmt. to 5660', top sand. RIH w/ Baker retr. squeeze tool set @5547'. Test 56-1 sand squeeze to 3000 psi. Held o.k. Pooh. RIH w/ Baker retr. head. Washed off sand 5660' to retr. BP @5705'. Pooh w/ BP. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. Cleaned to 5780', top sand above Baker Mod F pkr. Pooh. RU to run tbg. Ran 3 1/2" temp prod. test string w/ accessories. Set Baker FH 3 1/2" x 9 5/8" hydr. pkr above D Zone perfs. @5238'. Spaced out and landed tbg., RD BOE. Installed X-mas tree. Displaced mud above pkr @5238' w/ salt water. Installed BV. Started production testing at 3:00 p.m. 3/7/77. 12:00 midnite lifting loO BPD wtr. -]ASE TradingBay State UNI'al OIL C[ ?NN IF CALIFOPC,tlA t _CORD ~-LL NO, . TBS A-2 FIELD Tradinq Bay Field . . ~TE .~7 3/8/77 _~8 3/10/77 _~9 3/11/77 30 3/12/77 .1 3/13/-77 2 3/14/77 Same Headin Same Headin · Same Headin 6669'TD 6461 'ETD 9 5/8" csg. @6546' Baker Modl F perm. pkr! w/ plug @5796' Sand plug! @ 5796' -5780' Baker Mod_ D perm pkr - @6065' Same Headin< 6669'TD ] 6461'ETD 9 5/8" csg. @6546' Baker Mod D perm pkr @6065' Baker Mod perm. pkr w/ plug @5796' Top fill @ 5714' DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS 12:00 midnite to lO:O0 a.m. - lifting A-2. 207 bbls water. Compressor dwn. 10:00 a.m. - 7:00 p.m. Recovered 270 bbls water at 12:00 midnite. Moved rig to TBS A-4. RU BOE and cleaned sand for active mud tank. Recommenced WO activities on TBS A-2, 12'O1 p.m. 3/10/77. Moved rig to TBS A-2. RU slick line. Ran sinker bar to fill @5668' SLM. Ran press, temp survey. RD slick line. RU GO Int. Ran collar locator ( sinker bar) --found fill @5684'DIL. Reperforated 5532' to 5500' (54-9) sand, 5480' to 5450'(54-5 sand) and 5430' to 5400' (53-8 sand) of the "D" Zone. Produced well until stable. Ran spinner-tracer prod. profile log. Tagged fill w/ prod. logging tool @5714'. · Reperforated 5693' to 5660' (56-1 sand) of the "D" Zone. Produced well until stable. Reperforated 5640' to 5630' (56-1 sand) of same zone. Produced well until stable. Displaced tbg. and annul us above Baker RH pkr @5238' w/ 65# Dril-S WO fluid to kill well. Remove X-mas tree. Installed BOE. Pulled and layed dwn. tbg. w/ accessories RIH w/ ret. BP set @5440' below 53-8 sand, D Zone. Spotted 18 sx. sand on Baker retr. BP @5440'. Top sand @5410'. RIH w/ Baker retr. squeeze tool set @5328'. Broke dwn. top 53-8 sand (5400'-5410') @1800 psi to squeeze off gas. Pumped 5 cfm @1600 psi. Mixed 150 sx. Class "G" cmt. w/ .75% D-31, .3% D-19, .1% D-6. 50 cf cushion ahead and behind. Pumped away @ 3 cfm w/ 1200 psi building to 1600 w/ cmt. @ perfs. 3000 psi w/ 90 cf cmt. away. ISI 3300 pis. Held 15 min. Bled to O. Rev. out (1000 psi) 50 cf water, 50 cf cmt. Pulled 5 stands, SI 2 hrs. CIP 10:30 a.m. 3/14/77. Pooh. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper; Tagged cmt. 5331'. CO hard cmt. to 5410'. Closed rams and pressured to 2000 psi. Held o.k. CO hard cmt. to 5412', washed sand to 5433'. Circ. out. * 1 ll/160D, 6" long bull. 'plug w/ 15' 0.072" OD _wire on fill @5714' left from run 54-5 sand (5450' to 5480') 3/11/77. -]ASE_ Trading Bay State tlNIO l OIL COr,?AIIY OF CALIFO IIA RECORD I'~-tk ID, TBS A-2 FIELD Trading Bay Field kTE 33 3/15/77 3/16/77 '6 3/17/77 3/18/77 3/19/77 Same Headinc_ 6669 'TD · 6461 'ETD - fl. shoe 9 5/8" csg. @6545'. Baker Mdd: D perm pkr @6065' Baker Mod F perm pkr w/ K latch plug:: @5796' Sand plug! above Mod! F pkr 5796'- 5791' : 6669 'TD 6461 'ETD (fl shoe) 9 5/8" csg. @6546' Baker Modl D perm pkr @6065' Baker Mod- F perm i pkr @5796' Same Headinc 6669'TD 6461'ETD 9 5/8" csg. @6546' Baker Mod D per pkr @6065' Baker Mod F perm pkr @5796' Baker A-5 dlual hyd, pkr @5222' DETAILS OF OPEPATI~qS, DESCRIPTIC~IS g RESULTS RIH w/ Baker retr. head. Retr. Baker ret. BP @5440'. Pooh. RIH w/ Bowen junk basket w/ 6 1/4" oil jars. Tagged fill @5706'. Washed to 5721'. Cut from 5721' to 5723' w/o pump. Pooh Recovered 1' o.072" OD wire. RIH w/ same tool. Washed 5723' to 5738'. Pooh. Rec. 30' 0.072" OD wire. RIH w/ same tool. Back wash 5738' to 5765'. Circ. bottoms up. Pooh. Rec. 6' 0.072" OD wire & 6" x 1 11/16" bu' plug fish. Layed dwn. fishing tools. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 5791'. Pooh. RIH w/ ret. BP @1000'. Due to tbg. hanger being loose while testing BOE on 3/13/77, nippled dwn. BOE to inspect hanger spool. Screw which holds hanger in spool would not run in properly (too short), Unable to repair spool. Replacement on way as soon as weather breaks. Nippled up BOE. Retrieved BP @1000'. RU GO Int. Reperforated 57-2 sand (5785 to 5730'),'4 hpf, 54-5 sand (5480'-5450') and bottom Qf 53-8 sand (5430'-5420'), 2 hpf, of D Zone w/ 4" csg. guns. RD GO Int. RIH w/ Baker ret. BP set @1424'. Nippled dwn. BOE. Replaced defective Cameron tbg. hanger spool. Tested to 2500 psi. Nippled up & tested BOE o.k. RIH w/.5" DP and retrieved BP @1424'. RIH w/ fishing tool on 5" DP & ret. K latch plug in Baker Model F pkr @5796'. RIH w/ 700' 2 3/8" tbg. on 5" DP to' 6461'ETD, circ. bottoms up, no fill. Pooh. Ran dual 3 1/2" x.2 7/8" tbg. strings w/ accessories completing "D" Zone (SS) and Hemlock Zone LS) w/ future "E" Zone producing capabilities. RU slick line. Set tbg. plug in SS "XN" landing nipple @5761' Replaced GL valve w/ broken check valv. es @5149'. Set Baker A-~ dual hyd. pkr above "D" Zone perfs @5222' above "D" Zone perfs. PAGE 9 ]ASE Trading Ba_v_ Field UNIOfl OIL C[I,PN' Y OF.- CALIFODtIA tfCORD I,~LL ~), TBS A-2 . FIELD Trading Bay State_ ~TE 3/20/77 ;9 3/30/77 · 0 3/31/77 1 4/1/77 Same Headinc Same H6adin§ Same Heading 6669 'TD · 6461 'ETD 9 5/8" csg. @6546' Baker Mod D perm. pkr @6065' Baker Mod F perm. pkr @5796' Baker A-5 dual hyd. pkr.@5222, DETAILS OF OPERATIONS, I)ESCRIPTIC~IS & RESULTS Spaced out and landed tbg. Tested pkrs o.k. Removed BOE. Installed X-mas tree. Displaced mud opposite "E" Zone (6065'-5796') and "D" Zone '(5796'-5222') w/ diesel, displaced above A-5 dual hyd. pkr w/ FIW. Opened "XA" sleeve in SS @5727' for prod. of "D" Zone. Released rig to TBS A-4 12:00 midnite 3/20/77 Recommenced WO operations on TBS A-2 at 12:01 a.m. 3/30/77. Posi- tioned rig over TBS A-2. RU S.L_. Pulled ball valve in long and short string. RD S.L. RU GO Int. Run noise-temp density survey to find leaks and gas entry positions. Ran spinner-, temp-fluid density-noise logs to find leaks and gas entry. Found gas entry from 55-7 sand @5565'-~590' interval and hole ia L.S. @5742'. Released rig to TBS A-4 at 12'00 noon 3/31/77. Recommenced WO operations at 12:01 a.m. 4/1/77 on TBS A-2 Ran blank into all G.L. mandrels in S.S. Found S.S.o.k. Leak in btm. mandrel in L.S. No communication between D Zone and annulus above hyd. pkr @5222' ' Released_.~!g to TBS AL16 at 1.2'00 noon 4/1/77. '" .. PAGE Ih, ]o UI'IIOI OIL CgiP/ ff CALIFO 'IIA lfLL t<LCOI® 'CASE TRADING BAy STATE l'~LL 1,10, A 2 FIELD TRADTN~ RAY ~'!R.T.D ~TE ETD Letters to Correspond ~v/Tbg. Detail N M H G ' A JTS. 12 15 24 15 29 57 DETAILS OF OPEP~TIONS, DESCRIPTIOIIS & RESULTS TUBING DETAIL 3 1/2" & 2 7/8" SHORT STRING DESCRIPTION FOOTAGE Flow Head 2 7/8" Tbg. "XN" Nipple Otis 3.25OD,2.205ID . 2 7/8" Tbg. "XA" Sleeve, Otis 2 7/8" 3.75OD, 2.313ID 2 7/8" Tbg. 2 7/8" Blast Jts. 3.688 OD X 2.441ID "X" Over 2 7/8" Tbg 2 7/8" Blast Jts. 3.688OD X 2.441ID "X" Over 2 ://8" Tbg. "X" Over 3 1/2" Butt. to 2 7/8" 3 1/2" Butt. Tbg. "XA" Sleeve, Otis 3 1/2",4.28ID X 2.75 ID 3 1/2" Butt. Tbg. Telescoping Swivel Sub Baker (closed) 4.25 OD, 3.00 ID Pkr. pups 3 1/2" 3 1/2" pkr. hydrostatic dual Baker A-5 "X" Over left hd. safety sub 3 1/2" Tbg. "XA" Sleeve, Otis 3 1/2", 4.28 OD 2.75 ID 3 1/2" Tbg. Camco GLV 3 1/2" KBUG 5.50 OD, 2. 875 ID 3 1/2" Tbg. Camco GLV 3 1/2" KBUG 5.50 OD 2. 875 ID 3 1/2" Tbg. Camco GLV 3 1/2" KBUG 5.50 OD 2. 875 ID 3 1/2" Tbg. 3 1/2" 'Tbg. Pup 3 1/2" Tbg. Camco GLV 3 1/2" KBUG 5.50OD 2. 875 ID 3 1/2" Tbg. Camco GLV 3 1/2" KBUG 5.50 OD 2. 875 ID 3 1/2" Tbg. Camco GLV 3 1/2" KBUG 5.50 OD 2. 875 ID 3 1/2" Tbg. 3 1/2" Ball Valve. otis 2.75 OD 1. 500 ID 1.50 30.28 2.15 30.85 3 55 60 89 71 04 1 25 180 92 50 23 1 25 60 66 5O 31.00 4.00 29.97 3.80 3.10 6.82 .50 30.73 4.00 31.26 6.57 369.33 6.55 458.89 6.56 123.05 6.00 734.56 6.68 459.22 6.65 889.14 6.60 1752.83 2.30 BOTTOM 5795.88 5794.38 5764.10 5761.95 5731.10 5727.55 5666.66 5595.62 5594.37 5413.45 5363.22 5361.97 5301.31 5300.81 5269.81 5265.81 5235.84 5232.04 5228.94 5222.12 5221.62 5190.89 5186.89 5155.63 5149.06 4779.73 4773.18 4314.29 4307.73 4184.68 4178.68 3444.12 3477.44 2978.22 2971.57 2082.43 2075.83 323.00 TOP 5794.38 5764.10 5761.95 5731.10 5727.55 5666.66 5595.62 5594.37 5413.45 5363.22 5361.97 5301.31 5300.81 5269.81 5265.81 5235.84 5232.04 5228.94 5222.12 5221.62 5190.89 5186.89 5155.63 5149.06 4779.73 4773.18 4314.29 4307.73 4184.68 4178.68 3444.12 3437.44 2978.22 2971.57 2082.43 2075.83 323.00 320,70 PAGE 0IL CarPANY CALIFOR:,IIA _EASE TRADING BAY STATE I,~LL l,lO, A-2 FIELD __TRADING BAY FIELD ~TE ETD JTS. __ 9 DETAILS OF oPERATIONS, DESCRIPTIOHS & RESULTS TUBING DETAIL 3 1/2" & 2 7/,8" SHORT STRING (continued) DESCRIPTION FOOTAGE 3 1/2" Tbg. 3 1/2" Tbg. Pup 3 1/2" Tbg. Hgr. Rig Kelly Bushing to Tbg. Hgr. 277.25 6.O5 1.00 36,40 BOTTOM 320.70 43.45 37.40 36.40 NOTE: End of SS is in Baker Seal Assy. @ 5813.76. 2 7/8" Buttress Tbg. 3 1/2" Buttress Tbg. lZ its. 169 jts, TOTAL JTS. = 2 7/8" Butt. Tbg. 183 3 1/2" Butt. Tbg. 179 363.60' 5187.23' 5556.35' 5496.68' 11053.03 TOP __ ,' 43.45 37.40 36.40 UNIOI'I OIL C(I' PANY OF CALIFOF tlA 'ELL I,:LCOId.) i.F. AGE TRADING BAY STATE FIELD TRADING _BAY FIEf,D .,',ATE Numbers to Correspond w/Tbg. D etail 18 17 16 15 14 13 12 11 10 77 I ETD JTS. 12 14 14 :'i :DETA:iLS~ OF: OPE~:TI ONS, DESCRI PTIOIIS g RESULTS TUBING DETAIL 3 1/2" & 2 7/8" LONG STRING DESCRIPTION FOOTAGE 2 7/8" Mule Shoe 3.00ID, 3.95OD 2 7/8" Otis "XN" Nipple 3.25OD, 2. 205ID 2 7/8" Pup Joint Seal Assy. W/F 3.25 ~ore Baker Pkr. Baker Mod, "D" 190,32 Ret. Prod. Pkr. plain btm. set @ 6065'. 2 7/8" Pup Joint 2 7/8" Pup Joint 2 7/8" Otis "XA" Sleeve 3.75OD X 2. 313 ID "X" Over Baker Blast Jr. 3.688OD X 2,441ID 2 7/8" Otis "XA" Sleeve 3.75OD X 2,313 ID Seal Assy Baker for 6" Bore Pkr. Baker Mod. F-1 Ret. Prod. Pkr. Plain btm. set @ 5795'. Flow Head, Baker 2 7/8" Tbg. 2 7/8" Otis "XA" Sleeve 3.75 OD X 2. 313 ID 2 7/8" Tbg. "X" Over Bl~st Jr. Baker 3.688 OD X 2.441 ID 2 7/8" Tbg. "X" Over Blast Jts. Baker 3. 688 OD X 2.441 ID 2 7/8" Tbg. 2 7/8" Pup Jr. 2 7/8" Tbg. 2 7/8" Pup Jr. Tbg. 2 7/8" Pup Jr. Baker Pkr. Mod. A-5 Dual w/40,000# shear release w/LHS Conn. 2 7/8" Pup Jr, 2 7/8" Tbg, 2 7/8"'Otis "XA" Sleeve 3.75 OD X 2.313 ID. 2 7/8" Tbg. Camco GLV KBUG #5 5.50 OD, 2.875ID 2 7/8" Tbg. 2 7/8" Tbg. Pup 2 7/8" Tbg. Camco GLV KBUG #4 5.50OD, 2.875ID 2 7/8" Tbg. Tbg. Pup 2 7/8" Tbg. Camco GLV KBUG #3 5.50OD, 2,875ID 2 7/8" Tbg. 2 7/8" Pup Jr. .7O .75 11.00 21.20 6.10 8,57 3.55 1.25 221.19 3.55 17.88 1.50 29.66 3.55 92.59 1.25 70.68 181.03 1.25 50.31 90.73 6.10 31.00 6.10 1.75 6.82 3.00 30.78 3.55 29.88 6.64 364.71 10.25 212.22 6.65 242.66 8.05 424.97 6.88 424.77 10.20 BOTTOM 6092.18 6091.48 6090.73 6079.73 6058.53 6052.43 6043.86 6040.31 6039.06 5817.87 5814.32 5796.44 5794.94 5765.28 5761.73 5669.14 5667.89 5597.21 5416.18 5414.93 5364.6'2 5273.89 5267.79 5236.79 5230.69 5228.94 5222.12 5219,12 5188.34 5184.79 5154.91 5148.27 4783.56 4773.31 4561.09 4554.44 4311.78 4303.73 3878.76 3871.88 3447.11 TOP 6091.48 ,6090.73 6079.73 6058.53 6052.43 6043.86 6040.31 6039.06 5817.87 5814.32 5796.44 5794.94 5765.28 5761.73 5669.14 5667.89 5597.21 5416.18 5414.93 5364.62 5273.89 5267.79 5236.79 5230.69 5228.94 5222.12 5219.12 5188.34 5184.79 5154.91 5148.27 4783.56 4773.31 4561.09 4554.44 4311.78 4303.73 3878.76 3871.88 3447.11 3436.91 UNION OIL CQ /PANY OF CALIFOPC IIA I',ELL l<LCOl® ~_ASE TRADING BAY STATE I'~LL l~'~O, A-~. FIELD TRADING BAY FIELD .ATE Numbers to Correspond w/Tbg. Detail ETD JTS. 12 29 14 21 10 DETAILS OF'OPERATIONS, DESCRIPTIOHS &' RESULTS TUBING DETAIL 3 1/2" & 2 7/8" LONG STRING (continued) DESCRIPTION FOOTAGE BOTTOM TOP 2 7/8" Tbg. Camco GLV KBUG #2 5.50OD, 2.875ID 2 7/8" Tbg. 2 7/8" Pup Jt. 2 7/8" Tbg. Camco GLV KBUG #1 5.50OD,2.875ID 2 7/8" Tbg. 2 7/8" Tbg. Pup 2 7/8" Tbg. 2 7/8" Tbg. Pup Jr. 2 7/8" Tbg. 2 7/8" Tbg. P. up Jr. 2 7/8" TBg. 2 7/8" Pup Jr. 2 7/8" Tbg. 2 7/8" & 3 1/2" Butt. "X" Over 3 1/2" Tbg. Otis Ball Valve 2.75 OD, 1.500 ID 3 1/2" Butt. Tbg. 3 1/2" Butt. Tbg. Pup Tbg. Hgr. Rig KB to Tbg. Hgr. 363 64 6 68 90 06 6 15 886 65 6 65 273 28 6 10 425 08 6 20 635 92 6 12 301 62 6 14 61.50 I 30 30 76 2 30 278 69 4 67 1 00 36.40 3436.91 3073.27 3O66.59 2976.53 2970.38 2083 73 2077 08 1803 80 1797 70 1372 62 1366 42 73'0 50 724 38 422 76 416 62 355 12 353.82 323.06 320.76 42.07 37.40 36.40 3073.27 3066.59 2976.53 2970.38 2083.73 2077.08 1803.80 1797.70 1372.62 1366.42 730.50 724.38 422.76 416.62 355.12 353.82 323.06 320.76 42.07 37.40 36.40 --0-- 171 Jts. of 2 7/8" Tbgo - 5192.75' 10 Jts. of 3 1/2" Tbg. - 309.45' String Wt. Dwn. - 76,000# Both Latched Up - 105,000# KB to tbg. hgr. 36.40 PAGE NO. 14 NOTE: See SS Tbg. Detail for letters & the LS Tbg. Detail for numbers. 13 3/8" Csg. set @ 1023' M N 12 13 Top of dual "A5" Baker pkr. @ 5222.12' w/ LHS conn.-40,000# shear release. Top of dual Baker pkr. @ 5796.44'. Btm. of SS @ 5795.88'. 14 15 REV. "1 DATE 16 Top of single Baker pkr. @ 6058.53' 9 5/8" Csg. set @ 6546'. Btm. of LS @ 6092.18'. WELL SCHEMATIC TBS A-2 TRADING BAY FIELD Started 2/25/77 Completed 4/1/77 D~AV,'N. -- C~D. ~ AI'I"D. SGAI.~ OAT~ UNION OIL COMPANY Oi:: CALIFORNI^ .' ( Union Oil and Gas [ _don: Western Region Union Oil Company of California p.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union 'June 17, 1977 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska TBS~ A-4, MONOPOD 99502 Dear Mr Hamilton: Enclosed for your files are two (2) copies each of the Sundry Notice & Reports on Wells (Form 10-403) for the above captioned wells. Very truly yours, Gary E. Carlson Engineer sk- · Encl. (4) cc: Marathon Oil Co. Rodney Smith-USGS /Orm 10-403 ,,,/REV. 1-10-73 / Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL il OTHER SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOI~ : ........ P. O. Bo× 6247; A~ohn~g~: AI~]~= 4. LOCATION OF WELL At surface 1613'N, 570'W of the SE corner. Section 4: T9N, R13W, S. M. 99502 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RT 101' above MSL. 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 133-10056-00 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME T¥~cl{~c~ R~y .qt:t~ A-2 10. FIELD AND POOL, OR WILDCAT Trading Bav-M~HI~ 11. SEC., T.,'I~., M., ['BOTTOM H~)LE OBJECTIVE)- Section 4: T9N, R13W, S. M. 12. PERMIT NO. 66-49 )oft, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTI PLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT II ALTERING CASING I1 SHOOT !,NG ABANDONMENT* /.J_~~'est zones sePa_~ra.'~_ (NOT : tlple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The "D" Zone will be tested separately in TBS A-2 to verify suspected communication between the "D" Zone and the Hemlock Zone. If the communication is verified, tests will be obtained on the "D" Zone only. The allocation of production between zones will be based on these tests. Procedure: 1. RU slick line on TBS A-2 LS. 2. Pull BV. 3. Run & set Otis "PX" plug in "XN" nipple @ 6091'. 4. Rerun BV. 5. Production test both strings. 6. Pull BV, pull "PX" .plug, & rerun BV. 7. Return well to production. 16. I hereby certify~that the foregoiBg is true and correct SIGNED ~_. /A.iarV E. Carlson .. T~TLE__ Engineer DATE 6/16/77 (This space for State office use) APPROVED BY TITLE , CONDITIONS OF APPROVAL, IF ANY: (~ ~/~-Y'~ '/t'~'~~~~s~ons On Reverse Side DATE ..-.. Union Oil and Gas Di on' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union May 31, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 PorcuPine Anchorage, Alaska 99504 RE' MONOPOD PLATFORM Dear Mr. Hamilton- Enclosed for your approval are two (2) copies each of the completed Sundry Notices and Reports on Wells form for the above captioned projects. Sincerely yours, '-~.~.im ~. Callender D'l'i'~tq. Drlg. Supt. Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals,) i. o,- ~ GAS r-1 WELLI I WELL OTHER 2. NAME OF OPERATOR Union Oil Co. Of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, Alaska 99502 4. LOCATION OF WELL Atsurface 1613'N 570'W of the SE Corner 4' 19N, R13W, S.M. Section 13. ELEVATIONS (Show whether DF, RT, GR, etc.) ll2' RT above HLLW 14. CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L---J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 5. APl NUMERICAL CODE 133-10056-00 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9, WELL NO. A-2 10. FIELD AND POOL, OR WILDCAT Trading Bay- Middle Kenai-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 4' T9N, R13W, S.M. 12. PERMIT NO. 66-49 ~ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) See below (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Fracture stimulated the Hemlock Zone, perforate the "D" Zone and recomplete as a "D-Hemlock" producer with the "E" Zone isolated by paCkers. Procedure' · 2. 3. 4. 5. 6. e 0 10. Changed out tbg. spool· Squeezed and tested top Hemlock, 56-1 sand and bottom 57-2 sand for zone isolation. Fracture stimulated Hemlock Zone. Perforated "D" Zone perfs 5730' -_.5785', 5623' - 5693' 5500' to 5532' 5450' to 5480', 5400' to 5430'. Completed well as Dual "D" Zone, hemlock oil producer with "E" sands isolated by dual hyd. pkrs. Pulled 3 1/2" x 2 7/8" dual strings of tbg. and layed down due to e essive sand production. Killed well with Dril-S completion fluid· Installed BPV. Removed X-mas tree. Installed & tested BOPE. PUlled and layed dOwn dual 2 7/8" tbg. strings with accessories. Ran GR-CBL-VDL, CNL and T.D.T. logs from 5875' to 3800'. 16. , hereby that the ~o~_~_~s ,~nd corec,, / SIGNED // ~i~i R, Cai ]~lld~r' TITLE . (This space/or State office use) Dist. Drlg. Supt. DATE ...5/..20/77 APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Sundry Notices and Reports on Wells Page 2 May 20, 1977 11. Squeezed sand-gas source of 56-1 sand 5623' to 5660' with Glass "G" cement. 12. Ran production test on "D" Zone. ~ f 13. Squeezed top 53-8 sand (5410' to 5400'). 14. Cleaned out hole to top ~Model F perm. pkr. at 5796'. 15. Completed well as a Dual "D" - Hemlock oil producer with "E" sands isolated by dual hyd. pkrs. with capability of producing the "E" sands from either string. Union Oil and Ga~ ~' ' /~s~on' Western Region Union Oil Company oi California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union May 13, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99502 TBS A-16 TBS A-13 MONOPOD PLATFORM Dear Mr. Hamilton: Enclosed for your information are two (2) copies of the Monthly Report of Drilling and Workover Operations for the above captioned projects'. Si ncerely yours_, Jim R. Callender Dist. Drlg. Supt. cc- Marathon Oil Co. Rodney Smith - USGS Harry Lee RECEIVED ~cV. 3- I-?0 STATE OF')kLASKA OIL AND GAS CONSERVATION COMMI1WEE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER NAME OF OPERATOR Union 0ii Company of California ADDRESS OF' 'O~PERATOR P. 0. Box 6247, Anchorage, Alaska 99502 LOCATION OF WELL 1613'N, 570'W of the SE Corner. Section 4: T9N, R13W, S.M. SUBMIT IN DUPLICA'I~ API NUM~ER1CAL bODE 33- ] 0056-00 6 LEASE DESIGNATION AND SESIAL NO. ADL-18731 IF INDIA~, ALOTTEE OR TRIBE NAME 8. L,~IT FA/{~ OR LEASE JgA]~E Trading Bay State 9 WELL NO A-2 10 FLELD AND POOL. OR WILDCAT lrading Bay-Middle Kenai-Hem]ock 11 SEC, T., R., 1~[. (BO~I'OM HOI~ Section 4' T9N, R13W, S.M. ,,, , ~2. Vm, UVaT ~rO. 66-49 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-I~NGES IN HOLE SIZE, CAS1NG AHD CEMENTING JOBS INCLUDING DEPTH SET AiNrD VOLLrlVrES USED. PF.R.FORATIONS, TESTS AND RESULTS FISHING JOB~ JI/NK IN HOLE AND SIDE-TRACKED HOLE AND A_NY OTHER SIGNIFICANT C'/{ANGES IN HOLE CONDITIONS 41 4/1/77 6669 'TD 6461 'ETD 9 5/8" csg. @6546' Baker Mod D perm. pkr @6065' Baker Mod F perm. pkr. @5796' Baker Mod A-5 dual hyd. pkr @5222'. Recommenced WO operations at 12:01 a.m. 4/1/77 on TBS A-2. Ran blank into all G.L. mandrels in S.S. Found S.S.o.k. - leak in btm. mandrel in L.S. No'communication between D Zone and annulus above hyd. Pkr. @5222'. Released rig to TBS A-16 at 12:00 noon 4/1/77. 14. I hereby'certi£y that the ,~oregoir~i~ true ~ ~ '" ~ ' "' ' s,~~~~/~~'~~ Dist. Drlq. SuPt._ ~,5/!3/77 NOT --Repo o t is o~.s qu'r o . ~ ~ g oil and gQS conservation commi~ee bythe 15~ of the suocNdin9 Mn~, ~lo~ otherwise directed. Union Oil and G~ ~ivision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907)276-7600 - i'-- m-~= '~' "5' ' , ,c~ ' ~'V~'l ............. ' ........ . Hr. Ho~le HamJ 1ton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 CC' Dear Mr. Hamilton' Enclosed for your information are (2) copies of the Monthly Report and Workover Operations for the above captioned projects. Sincerely yours, ~ ~. Callender ~ Drlg. Supt. Marathon Oil Co. Rodney Smith - USGS Harry Lee RECEIVED ~'~rm ~o. P--4 R~V. a- I-?0 STATE OF ALASKA OIL AND OAS CO'NSERVATION COAAMII~EE MONTHLY REPORT OF DRILLING AND' WORKOVER OPERATIONS 1. WELL WELL OTHER SUBMIT IN DUPLICAT~ 2. NAME OF OP~ATOR Union Oil Co. of Calif. 31 ~,DflRESS OF OPE~.TOa P. O. Box 6247, Anchorage, Alaska 99502 Rl:L iv=u 4 LOCATiON OF W~J,~- 1613' N, 570' W of the SE Corner, SectiOn 4' T9N, R13W, S.M. APl NU~[ERICAI, CODE 133- ] 0056-00 LEASE DESIGNATION A.XD SEI~IAL NO. ADL-18731 8. L~,'IT FAri~M OR LEASE )qA_ME Trading Bay State A-2 lO FL~ AND P~L. OR WII.DCAT Trading Bay-Middle Kenai-Hemlock n s~.c, T.. ~. ~. (~o~ro~ HOU~ OB,mC'TrWF.~ Section 4: T9N, R13W, S.M. 12 PEP~ IT 66-49 ¸20 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PF~R,FOHATIONS, TESTS A2CD HESULTS FISHING JOBS JIYNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTH3ER SIGNIFICANT CHANGES IN HOLE CONDITIONS 3/1/77 6669'TD Recommenced WO activities on TBS A-2 at 12:01 a.m. 3/1/77. 6461 'ETD Killed L.S., S.S; & Annulus between Baker Mod F pkr @5796' (fl. collar) and Baker A-5 hyd. pkr @5246' w/ 5% KCL Dril-S W.O. fluid. 9 5/8" csg. Pumped dwn. S.S. thru XA sleeve at 5216' and circ. out gas @6546' cut mud in annulus above dual pkr at 5246'. Unable to release Baker A-5 hyd. dual pkr at 5246' . RU GO Int. Ran free point to pkr at 5246' pkr @5246' in S.S. tbg. Tbgl stuck at pkr. Cut S.S. above pkr at 5240'. Baker Mod F perm pkr @5796' Baker Mod D perm. pkr @6065' ¸21 ~22 3/2/77 6669'TD Cut 2 7/8" L.S. @5225', 21' above Baker A-5 Dual Hyd. Pkr. 6461'ETD 'set above D Zone @5246'. Pooh w/ 2 7/8" L.S. tbg. and layed (fl. collar) dwn. same. RIH w/ Tri-State O.S., and jars on 5" DP. Engaged 9 5/8" csg. top of fish @5225'. Jarred fish loose. Circ. bottoms up. @6546' Pooh and layed dwn Baker A-5 ~dual hydl pkr & dual tbg. strings Baker Mod F hung below pkr. Found 2" diam. blast holes in both long and perm.pkr@5796' short strings @5664' (5649' DIL meas) opposite 56-1 sand perfs Baker Mod D @5623' to 5693'. Recovered total fish, well clear of tbg. perm. pkr @6065' 3/3/77 Same Heading RIH w/ 700' 2 3/8" tbg. stinger on 5" DP. Washed sand opposite Hemlock perfs. @6275' to 6461' ETD. Pooh. RU GO Int. Logged 5795' to 5000' w/ CBL-VDL. RIH w/ Baker 6" latch plug for 9 5/8" Mod F perm. pkr @5796' on W.L. Set plug in place. RD GO Int. Spot sand on top of same w/ 5" DP @5795' to 5780' ~--~x~~_~.-~cx~~~x~ ~~V. {' Dist. Drlq. SupS_, r,~. April 12, 1977 ._~--~ ~4:~ t~ ~ 1 1 ~ -- J ~ .. - r~ '.~ ~ ......... NOTE~ th~o~ G';~ired for ~Q~i c~iendor ~,h, ,,gordles, of th, ,totu, of operoti~fl;-' ond must ~ tiled in dupli=~, with oil and gos conservatbfl commiflee by the 15~ of the suoc~diflg ~n~, mle~ ~therwis~ dir.cted. 23 24 25 26 27 28 3/4/77 3/5/77 3/6/77 3/7/77 3/8/77 3/10/77 Same Heading RIH w/ Baker 9 5/8" retr. B.P. on 5" DP set @5705'. Spot sand 5705' to 5660'. Pooh. RIH w/ Baker retr. squeeze tool. Set @5547'. Broke dwn. 56-1 sand perfs (5623' to 5693') @ 2800 psi, 3 cfm @260b psi. Mixed 5Q sx. Class "G" cmt. w/ .75% D-31, .3% D-19 and .1% D-6. Used 50 cf water cushion ahead and behind cmt. ~Squeezed same.@ 3 cfm w/ 2600 psi. 21 cf to perfs. ISI 2800 psi, SI 5 min 1800 psi, SI 10 min. 900 psi, SI 15 min. 0 psi. Rev. out 50 cf water. CIP at 4:30 p~m. 3/4/77. WOC 8 hrs. Same Heading RIH w/ bit & 9 5/8i' csg. scraper. Cleaned hard cmt. 5590' to 5595',.stringers to 5660', top sand. Pooh. RIH w/ Baker retr. squeeze tool set @5547' Broke dwn. same sand w/ 2800 psi,'3 cfm @2600 psi. M~ved tool to 5645', spotted 50 cf water on bottom: Reset tool @5547'. Mixed 100 sx., same mix Class ."G" cmt. Used 50 cf water cushion ahead & behind cmt. Squeezed @ 3cfm w/ 3400 psi. 76 cf away. ISI 3400. Held 15 min. Rev. out 7 cf cmt., 50 cf water. CIP 11:00 a.m. 3/5/77. Pooh w/ tool. WOC 7 hrs. RIH w/ bit and 9 5/8" csg. scraper. Drilled hard cmt. to 5660', top sand. Same Heading RIH w/ Baker retr. squeeze tool set @5547'. Test 56-1 sand squeeze to 3000 psi. Held o.k. Pooh. RIH w/ Baker retr. head. Washed off sand 5660' to retr. BP @5705'. Pooh w/ BP. RIll w/ 8 1/2" bit & 9 5/8" csg. scraper. Cleaned to 5780', top sand above Baker Mod F pkr. Pooh. RU to run tbg. 6669 'TD 6461 'ETD (fl. collar) 9 5/8" csg. csg. @6546' Baker Mod FH hyd. pkr@5238' Baker Mod F perm. pkr w/ pl ug@5796' Sand plug5796'- '5780' Baker Mod D perm. pkr @6065' Ran 3 1/2"' temp prod. test string w/ accessories. Set Baker FH 3 1/2" x 9 5/8" hydr. pkr. above D Zone perfs. @5238'. Spaced out and landed tbg., RD BOE. Installed X-mas tree. Displaced mud above pkr @5238' w/ salt water. Installed BV Started production testing at 3:00 p.m. 3/7/77. 12:00 midnite liftin9 100 BPD wtr. RECEIVED APR Dlvi ion ,. rwtlon Same Heading 12:00 midnite to lO:O0 a.m. - lifting A-2. 207 bbls water. Compressor dwn. 10:00 a.m. - 7:00 p.m. Recovered 270 bbls water at 12:00 midnite. Moved ri9 to TBS A-4. RU BOE and cleaned sand for active mud tank. Same Heading Recommenced WO activities on TBS A-2, 12:01 p.m. 3/10/77. Moved rig to TBS A-2. RU slick line. Ran sinker bar to fill @5668' SLM. Ran press, temp. survey. RD slick line. RU GO Int. Ran collar locator (sinker bar) - found fill @ 5684'DIL 29 30 31 32 3/11/77 Same Heading Reperforated 5532' to 5500' (54-9) sand, 5480' to 5450' 54-5 sand)and 5430' to 5400'J(53-8 sand) of the D Zone. Produced well until stable. Ran spinner-tracer prod. profile log. Tagged fill w/ prod. logging tool @5714'. 3/12/77 6669'TD 6461 'ETD 9 5/8" Csg. @6546' Baker Mod F perm pkr. w/ plug @ 5796.' Sand plug@ 5796'-5780' Baker Mod D perm pkr @ 6065' Reperforated'5693' to 5660' (56-1 sand) of the D Zone. Produced well until stable. Reperforated 5640' to 5630' (56-1 sand) of same zOne Produced well until stable. Displaced tbg. and annulUs'above Baker RH pkr @5238' w/ 65# Dril-S WO fluid to kill well. 3/13/77 Same Heading Remove x-mas tree. Installed BOE. Pulled and layed dwn. tbg. w/ accessories. RIH w/ ret. BP set @5440', below 53-8 sand, D Zone. 3/14/77 6669 'TD 6461 'ETD 9 5/8" csg. @6546' Baker MOd D perm. pkr@6065' Baker Mod perm. pkr. w/ plug @5796' Spotted 18 sx. sand on Baker retr. BP @5440'. Top sand @5410' RIH w/ Baker retr. squeeze tOOl set @5328'. Broke dwn. top 53-8 sand (5400'-5410') @1800 psi to squeeze off gas. Pumped 5 cfm @1600 psi. Mixed 150 sx. Class "G" cmt. w/ .75% D-31, .3% D-19, .1% D-6. 50 cf cushion ahead and behind. Pumped away @ 3 cfm w/ 1200 psi building to 1600 w/ cmt. @ perfs. 3000 psi w/ 90 cf cmt. away. ISI 3300 psi. Held 15 min. Bled to O. Rev. out (1000 psi) 50 cf water, 50 cf cmt. Pulled 5 stands, SI 2 hrs. CIP 10:30 a.m. 3/14/77. Pooh. RIH w/ Top fi11@5714' 8 1/2" bit & 9 5/8" csg. scraper. Tagged cmt. 5331'. CO * hard cmt. to 5410'. Closed rams and pressured to 2000 psi. Held o k. CO hard cmt. to 5412' . , washed sand to 5433'. Circ. out. *l ll/16" OD, 6" long bull plug w/ 15' o.072" OD wire on fill @5714' left from run 54-5 sand (5450' to 5480') 3/11/77. 3/15/Y7 same Heading - RIH w/~Baker, retr~ head. Retr. Baker ret. BP @5440'. Pooh. ? RIH w/ Bowen junk basekt w/ 6 1/4" oil jars. Tagged fill @ 5706'. Washed to 5721'. Cut from 5721' to 5723' w/o pump. Pooh. Recovered 1' 0.072" OD wire. RIH w/ same tool. Washed 5723' to 5738'. Pooh.. Rec, 30' 0.072" OD Wire. RIH w/ same tool. Back wash 5738' to 5765'. Circ. bottoms up. Pooh. Rec. 6' 0.072" OD wire & 6" x 1 11/16" bull plug~i~h,,,~,y~wn, fishing tools. APR 34 3/16/77 35 3/17/77 36. 3/18/77 37 3/19/77 38 3/20/77 6669'TD RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 5791'. Pooh. RIH w/ 6461'ETD ret. BP @1000'. Due to tbg. hanger being loose while testing BOE fl. shoe on 3/13/77, nippled dwn. BOE to inspect hanger spool. Screw which 9 5/8" csg. holds hanger in spool would not run in properly (too short). @6546' Unable to repair spool. Replacement on way as soon as weather Baker Mod D breaks. Nippled up BOE. Retrieved BP @1000'. RU GO Int. perm pkr@6065' ReperfOrated 57-2 sand (5785 to 5730'), 4 hpf, Baker Mod F 54-5 sand (5480'-5450')and bottom of 53-8 sand (5430'-5420'), perm pkr w/ 2~hpf~ of.~D Zone w/ 4"~csg..guns. K latch plug @5796' Sand Plug above Mod F pkr 5796'- 5791' 6669'TD 6461'ETD (fl. shoe) 9 5/8" csg. @6546' Baker Mod D perm pkr @6065' Baker Mod F Perm. Pkr @5796' RD GO Int. RIH w/ Baker ret. BP set @1424'. Nippled dwn. BOE. .Replaced defective Cameron tbg. hanger spool. Tested to 2500 psi. Nippled up & tested BOE o.k. RIH w/ 5" DP and retrieved BP @1424'. RIH w/ fishing tool on 5" DP & ret. K latch plug in Baker Model F pkr @5796'. RIH w/ 700' 2 3/8" tbg. on 5" DP to 6461'ETD, circ. bottoms up, no fill. Pooh. Same Heading Ran dual 3 1/2" x 2 7/8" tbg. strings w/ accessories completing "D" Zone (S.S.) and Hemlock Zone (L.S.) w/ future "E" Zone prod- ucing capabilities. 6669'TD 6461 'ETD 9 5/8" csg. @6546' Baker Mod D perm. pkr @6065' Baker Mod F perm. pkr@5796' Baker A-5 dual hyd. pkr @5222' RU slick line. Set tbg. plug in S.S. "XN" landing nipple @5761'. Replaced G.L. valve w/ broken check va!ve~)5149'. Set Baker A-5 .pkr "D" . dual hyd above "D" Zone perfs @5222'. above Zone perfs -RECEIVED Same Heading Spaced out and landed tbg. Tested pkrs o.k. Removed BOE. In- stalled X-mas tree. Displaced mud opposite "E" Zone (6065'-5796') and "D" Zone (5796' to 5222') w/ diesel, displaced above A-5 dual hyd. pkr w/ FIW. Opened."XA" sleeve in S.S. @5727' for prod. of "D" Zone. Released rig to TBS A-4 12:00 midnite 3/20/77. 10 3/28/77 11 '3/29/77 Same Heading Same Heading Tested Guiberson Mod A-R drillable prod. pkr w/ seals on 5" DP, Pkr was not set. Pooh w/ DP & seals. RIH w/ 8 1/2" bit, jars and bumper sub. Pushed pkr to bottom @3510'ETD. Pooh. Barite gel mud system contaminated w/ cmt. RIH w/ bit & scraper. Displaced mud w/ 68 pcf KCL, Dril-S WO fluid. Pooh w/ 8 1/2" bit & 9 5/8" csg. scraper. RIH w/ Baker ret. pkr on 5" DP. Tested csg. for good setting area from 3292' to 3260' o.k. Pooh. RU Schlumberger. Set Baker Mod D perm. prod. pkr @3270' W.L. between 24-A:sand (1660' to 1700') and 44-7 sand (3370' to 3490'). Run 2 7/8" seal lock tbg. and acc. w/ Baker hyd. pkr @1546' above 24-A sand located on perm. pkr ........ o.k. Nipple dwn. BOE. RU tree. ~~,O~Lq~_~f~,~zZ ....... sand @3382' ~o~o~ 3404'. Fluid level @1430'. Released midnite 3/29/77. RECEIVED 39 3/30/77 SameHeading 40 3/31/77 Same Heading Recommenced WO operations on TBS A-2 at 12:01 a.m. 3/30/77. Posi- tioned rig over TBS A-2. RU S.L. Pulled ball valve in long and short string. RD S.L. RU GO Int. Run noise-temp density survey to find leaks and gas entry positions. Ran spinner, temp-fluid density-noise logs to find leaks and gas entry. Found gas entry from 55-7 sand @5565'-5590' interval and hole in L.S. @5742'. Released rig to TBS A-4 at 12:00 noon 3/31/77. Union Oil and Gas Di:.,"""~,on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union March 15, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Re: TBS A-18 TBS A-2 Dear Mr. Hamilton: Enclosed for your information are (2) copies of the Monthly Report and Workover Operations for the above captioned projects. Sincerely yours, x.. ~_i_m_~J~l. Cal lender Dist. Drlg. Supt. CC: Marathon Oil Co. USGS -~Rodney Smith Harry Lee STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS NAM~ OF OP~I. ATOR Union Oil Co. of Calif. P. O. Box 6247, Anchorage, Alaska 99502 IX)CATION OF W'~-?~L 1613'N, 570'W of the SE corner, Section 4' T9N, R13W, S.M. SUBMIT l~l DUPLICAT~ APl NUiVlERICAL CODE 133-10056-00 LEASE DESIGI~ATION AND SEI:IIAL NO. ADL-18731 T IF INDIA]~ AI.,OTTEE OR TRIBE NAME 8. L,~IT F.~MILM OR LEASE NANIE Trading Bay State 9 WELL NO A-2 i0 FIFJ..D A.~ID POOl,. OH WILDCAT Tradin.q Bay-Middle Kenai-Hemlock Section 4: T9N, R13W, S.M. PEP.MIT NO 66-49 13,REPORT TOTAL DEPTH AT END OF MONTH. CHA. NGES IN HOLE SIZE, CASING AND CL'MENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFOHATIONS. TESTS A.N'D HESULTS FISHING JOP~ JI~"NK LN HOI..E AND SIDE-T'P,.ACKED HOLE Aa~TD ANY OTHER SIGNIFICANT CH-A~ ~ HOLI~ COI~'DITIONS Activated rig w/ partial crews from 12:01 a.m. 1/11/77 through 6:00 p.m. 1/21/77. Recommenced activating rig 12:01 a.m. 2/3/77 w/ full RU crews. Moved rig over TBS A-2. Rigging up misc. equip. RU W.L. to shift sleeve in long string. Shifting tool stopped,@6003'. "XO" sleeve @6025'. Ran 2 3/16" Imp. Blk 2 7/8" csg. tbg. collapsed to 2" ,.@6003'. 2/4/77 2/5/77 2/6/77 2/7/77 6669 'TD 6461 'ETD fl oat collar 9 5/8" csg. @6516' Baker Mod A Hyd. dual pkr @4585' Baker Model E hyd. single pkr. @6040' II II II II II II Finished RU and mixed mud to kill TBS A-2 C'ommenced WO operations on TBS A-2 12'01 a.m. 2/5/77. Killed well w/~68# Dril-S 5% KCL WO fluid. Circ. gas cut mud frOm 9 5/8" annulus. Communication between L.S. and S.S. between pkrs. S.S. in communication w/ annulus. RECEIVED MAR 1 6 1977 Set W.L. plug in L.S. Division cf Oil and G~s Conservg, tion Anchorage Nipple dwn, X-mas tree, RU BOE. Pulled S.S. clear of pkr. Tried to unseat pkr. w/ L.S. Ran free pt. Cut L.S. @4560'. Started laying dwn. dual 2 7/8" tbg. strings. Tongs broke dwn. at 10:30 p.m. Waited on parts. S,Gm~ ~_"~',,~--L-xl,'~.~ ak)kl~/~l'k~ =~..z Dist. Drlg. Supt. ,,~ 3/]5/77 , r~'"'~'l 1 ~- ~', ~ I ~ ~ - Y. JN'~ ___ oil ond gos conservation commtflee bythe 15~ of the suec~ding mn~, ~le~ otherwise directed. Page 2 March 15, 1977 4 2/8/77 5 2/9/77 II II II 6669 'TD 6461 'ETD fl oat collar 9 5/8" csg. @6546' Pulled 2 7/8" dual tbg. string. Changed out power tongs four times. Layed dwn. 2 7/8" tbg. string. Made up fishing tools. RIH on 5" DP to 4560'. Caught fish. Pooh. Left part in place @6026~'. RIH w/ O.S. & 2 7/8" grapple. Worked top fish to 6121'. Pooh. RIH w/ 3 5/8" grapple. 6 2/10/77 " " " 7 2/11/77 6669 'TD 5875' ETD BP 9 5/8" csg. @6546' 8 2/12/77 "" " 9 2/13/77 "" " l0 2/14/77 6669 'TD 5360' ETD retr. BP 9 5/8" csg. @65 46' Ran 7 5/8" OS. Caught fish @6121' Pooh. Left 18" junk tbg. in hole. RIH w/ 8 1~2" bit to 6461' Pooh. RIH w/ bit & 9 5/8" csg. scraper to 6461'. Circ. hole clean. Pooh. RU WL. RU Schlumberger. Ran GR-CBL-Sig., CNL, and TDT logs. RD Schlumberger. Set BP @1059'. Changed tbg. spool to Baker 12" 3000# X 10" 5000# and tested o.k. Set BP @5875'. RIH w/ 5" DP. Spotted 35 sx. sand @5865'. Tagged sand @5870' Spotted 35 sx. sand, tagged top sand @5815'.Clean. to 5825' Pooh. RIH w/ squeeze tool. Mixed and pumped 200 sx. Class "G" cmt. w/ .75% D-31, 0.3% D-19 and '0.1%,D-6. Broke dwn. perfs. @5820'-5825' w/ 2500 psi. Max. squeeze press. 4000 psi. Rev. out 90 cu. ft. cmt. Pooh. RIH w/ 8 1/2" bit & csg, scraper. Drilled cmt. from 5737'-5826' Circ. out sand to 5828'. Pooh. RIH w/ cmt. ret. set @~796'. Press. perfs. @5820'-5828' to 3800 psi. No, breakdown. RU GO Int. Ran 5" gun. Found fill @5817'. Pulled gun. Pooh. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 5833'. Pooh. RIH w/ c~t ret. set @5796' Broke dwn. perfs. @5820'-5833 ilO cfm @3000 psii. Pulled up to 5300'. RU GO Int. Ran 5" 4 spf t.t. gun. Perfed 5780' to 5785'. Set ret. @5796'. Tested blank @5785'-5820' for isolation w/ 1000 psi diff. Held o.k. Pooh. RIH w/ retr. head on 5" DP. Moved Baker retr. BP from 5880' and set @5360'. Spotted 25 sx. sand over BP. Ta§§ed top sand @5308'. Pooh. RU GO Int. RIH w/ 4" squeeze gun. Shot 5288'-5290', 4 hpf, RD GO Int. RIH w/ Baker retr. cmt. ret. set @5218'. Broke perfs. @2600 psi (22 cfm @2400 psi). Mixed 150 sx. Class "G" cmt. w/ .75% D-31, 0.3% D-19, 0.1% D-6. Pumped 50 cf water cushion, 150 sx. cmt., 50 cf water. Pumped 150 sx. cmt. @ bcfm w/ max. press. 3000 psi S.I. 1 hr. Bled to 0 psi. Rec. 5 cf fluid. Pulled Baker retr. cmt. ret. to 5077' Rev. out 30 cf clean water, 20 cf water cut cmt. W~C. Page 3 March 15, 1977 11 2/15/77 6669'TD CIP 8:40 p.m. 12/14/77. Pooh. RIH w/ 8 1/2" 5536'ETD (cmt) bit & 9 5/8" csg. scraper. Drilled cmt. 9 5/8" csg. 5225'-5300'. Pump sand to 5355'. Pooh. RIH @6546' Baker retr. tool. Circ. clean. Move retr. BP to 5670' Spot 25 sx. sand. Top sand @5615'. Pooh. R.U.'GO Int. Perf. 5590'-5592' w/ 4" squeeze gun, 4 hpf. RD GO Int. RIH w/ Baker retr. cmt. ret. set @5515'. Broke perfs. @5590'- 5592' w/ 2600 psi @ 4 cfm, 2200 psi on ann. Mixed 50 ~ sx. C1 "G" cmt. w/ 0.3% D-19, 0.1% D-6, .75% D-31. 50 cu.ft, cushion ahead & behind. Squeezed 22 sx. tp perfs, 28 sx. outside. Max. press. 2750 psi @ 5 cfm. SI 1 hr. Pulled tool to 5422'. Re~ out 40 cf water. No cmt. CIP 11:45 p.m. 2/15/77. Held 1800 psi on squeeze. WOC. 12 2/16/77 6669 'TD (float co l l ar ) ¢461 'ETD 9 5/8" csg. @6546' 13 2/17/77 6669 'TD 6461 'ETD 9 5/8" csg.@ 65 46' Bled press, off @3:00 a.m. Pooh w/ Baker retr. cmt. met. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. Tagged cmt. @5536'. C.O. to 5602'. Pooh. RIH w/ ~etr. tool; F.U, retr. BP. Pooh. RIH W/ 8 1/2"' bit & 9 5/8" csg. scraper to 6461'. Pooh. R.U. GO Int. Ran CBL-CNL-Collar log to 6461'. RD GO Int. Stand DP in derrick. Broug~ Dowell frac. equipment on deck. RU Dowell. 14 2/18/77 6669 'TD 6461 'ETD 9 5/8" csg. @m6~46' RU Dowell to frac. Hemlock Zone. Mixed frac. fluid. RIH w/ retr. pkr. on 5" DP. Set pkr. above Hemlock Zone @6045'. for frac. job on perfs. @6110'-6140', 6150'-6285', 6300'-6420'. Tested surface lines to 6000 psi. Tested pkr. and liner bond @2000 psi surface. Injected 48 bbls 12% HC! +3% HF +.4% Al30 +7% U66. Close bypass and press, annulus to 700 psi. Pump 124 bbls frac. fluid at 2600 psi. Injected 120 bbls 0.5 ppg sand @2800 psi at 15 BPM. 228 bbls 1 ppg sand @2500 psi 264 bbls 2 ppg sand ~3000 psi max. 216 bbls 3 PP9 Sand @3200 psi max. 375-:~bbls 4 ppg' sand @3600 psi max.. 72 bbls frac. fluid @3800 psi max. Injected 55 bbls frac. fluid @ 5 BPM @4200 psi max. 5 min. SI 2900 psi l0 min. SI 2450 psi 30 min. SI 1450 psi Pooh w/ pkr. RIH w/ bit & csg. scraper. Clean sand from 6387'-6461 "TD. Pooh. Page 4 March 15, 1977 15 2/19/77 16 2/20/77 17 2/21/77 18 2/22/77 II II II II I! II II II II 6669 'TD 9 5/8" csg. [a_6546 ' Baker dual hyd. pkr. @5276' Baker Mod F dual perm. pkr. @5796' Baker Mod D single perm. pkr. @6063'. RU GO Int. Ran GR 6460'-5300'. Perf. D Zone sands in 8 runs, 5730'-5785', 5623'-5693', 5500'-5532', 5450'-5480', 5400'-5430' @ 4 hpf. RD GO Int. RIH w/ bit & scraper to 6461'. Pooh RU GO Int. Ran junk basket & gauge ring to 6461'. No junk. RIH on W.L. Baker Model D 9 5/8" x 2 7/8" single perm. pkr. set above Hemlock @6065'. RIH on W.L. Baker Mod F dual 9 5/8" X 2 7/8" X 3 1/2" perm. pkr. set between D & E Zones @5796'. RD GO Int. Ran dual 2 7/8" x 3 1/2" tbg. str. w/ jewelry. Stabbed into Baker Mod D pkr. @6065'. Tested to 700 psi. Spaced out, landed tbg. Set Baker hyd. pkr. above D Zone perfs. 5238'. Tested all pkrs. to 700 psi above & below o.k. Removed BOE. Installed X-mas tree. Tested to 5000 psi. Displaced mud w/ diesel between Baker Mod D & Mod F & hydraulic pkrs. Displaced mud w/ salt water above dual hydraulic pkr. RIH w/ W.L. to set BV in L.S. Unable to get BV to latch due to X over directly below BV mandrel. Tri State made 2 7/8" K valve X over to BV dummy. RIH w/ K valve. Set press. @ 50 psi tbg. S.S. BV in place. Moved rig off TBS A-2 to TBS A-18 12:00 midnite 2/22/77 19 2/24/77 6669'TD 9 5/8" csg. @~6546' Baker Mod F dual perm. pkr. @5796' Baker Mod D single perm. pkr.@6063' A-2L 2/24/77 (last 12 hr. average) Gross Cut Net GOR GLR Gray..T_bg/csg. Press 733 16% 616 2588 3202 32.4 610/913 A-2S 2/24/77 (last 2 hr average) Gross Cut Net GOR GLR Gray. T.bg/csg.. Press 474 ~ 437 ..... (SI due to sand cut bean.) Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 Union Oil and Gas "~,ision: Western Region __ 3 ~:~;',~G ~'; unl®n May 13, 1976 99504 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 5 ENG .... SEC CONFER: FILE: RE: TBS A-2 MONOPOD PLATFORM Dear Mr. Hamilton: Enclosed for your approval are three (3) copies of the Sundry Notice & Reports on Wells (Form 10-403) for the above captioned workover, Very truly yours, David A. Johnson Drilling Engineer sk Encl. (3) cc.: Marathon Oil Co, Rodney Smith-USGS STAT E 0 F,~ S KA OIL AND GAS CONSER. .,~TION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for ProPosals tO c[rlll or to cleeoen Use **APPLICATION FOR PERMIT--" for ~uch proposals.) ,- y~E LL ~iZ..~j W ELL OTHER 2. NAME OF OPERATOR UNION OIL CO. OF CALIF. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, Alaska 99502 4. LOCA%ION OF WELL ^tmrf,ce 1613'N, 570'W of the SE corner. Section 4: T9N, R13W, S. M. ]3, ELEVATIONS (Show whether DF, RT, GR, etc_) 112' RT above MLLW 34. Check Appropriate Box To Indicate Nature of Notice, Re 5, ~'~'~NUMERICALCODE LEASE DESIGNATION AND SERIAL NO. ADL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT. FARM OR LEASE NAME Trading Bay State 9. WELL NO. A-Z J0. FIELD AND POOL, OR WILDCAT Trading Bay-Hidd]e Kenai-Hemlock ]1_. SEC.,T., R., M., (BOTTOM HOLE OBJECTIVE) Section 4: T9N, R13W, S. M. 12. PERMIT NO. 66-49 ~ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) *See Below SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT' (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ]5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ali pertinent details, and give pertinent elates, including estimated elate of starting any proposed work. *To fracture stimulate the Hemlock Zone, perforate the "D" Zone & recomplete as a D-Hemlock producer with the "E" Zone isolated by pkrs. PLAN OF PROCEDURE· le , 5. 6. 7. 1 Kill well w/ Dril-S completion fluid. Install BPV. Remove x-mas tree. Install & test BOPE.. Attempt to release tbe. hgr. from tbg. spool. If unable to pull free, cut tbg. strings immediately below hgr. PU BOPE & change out tbg. spool. Pull & laydwn, dual 2 7/8" tbg. strings & accessories. CO 9 5/8" csg. to 6461'ETD. Run GR-CBL-VDL Log & CNL Log from 6461'ETD to 3800'. Fracture stimulate the Hemlock Zone (prior to fracturing, squeeze blank from 6020'-6110' if required for pkr. point). Sqz. & test for. zone isolation between the "D" & "E" Zone in the interval from 5798'-5818'. hereby ce.i~.[.fy that the foregoing IS true and correct SIGNE ' ,]'im R' /Cial!,-,~rtr~ ~ TITLE .. Dist. Dr]g. Supt. O~TE 5/]4/76 See Instructions On Reverse Side PAT E Approved Copy TBS A-2 SUNDRY NOTICE (10-403) -2- May 14, 1976 9. Sqz. for zone isolation above the "D" Zone in the interval from 5230'-5290' if determined necessary from the cmt. bond log. 10. Perf. the "D" Zone as determined from the CNL Log. (Proposed perfs. shown on attached perforating sheet). 11. Perform DST on "D" Sds. 12. Complete well as a Dual "D"-Hem]ock Oil Producer w/ the ':E" Sds. isolated by dual hyd. pkrs. & w/ the capability of producing the "E:' Sds. from either s:ring. ESTIMATED TIME OF OPERATION Twenty (20) Days. Sand E Zone - 58-1sd E Zone - 58-7sd E Zone - 60-0sd Hemlock Zone Hemlock Zone Hemlock Zone PRESENT PERFO?~TIONS Interval Footage 5820-5850 30' 5900-5960 60' 5990-6020 30' 120' 6110-6140 30' 6150-6285 135' 6300-6420 120' 285' Remarks Short strir, g (gas) Short st:'irg (gas) Short string (gas) Long string (oil) Long string (oil) Long string (oil) D Zone - 53-0 sd D Zone - 53-8 sd D Zone - 53-8 sd D Zone - 54-5 sd D Zone - 54-9 sd D Zone - 56-1 sd D Zone - 57-2 sd E Zone - 58-1sd E ~'~ 58-7sd E Zone ~ ~ - ~O-~sd Hemlock Zone Hemlock Zone Hemlock Zone PROPOSED 5305-5330 25' 5365-5378 13' 5395-5430 35' 5450-5480 22' 5500-5538 38' 5623-5693 70' 5730-5785 55~ 258' 5820-5850 30' 5900-5960 60' 5990-6020 30' 120' 6110-6].40 30' 6150-628.5 135' 6300-6420 . 120' 2S5' Short svring (oil) Short strirg (oil) Short stri~ (oil) Short svripg (oil) Short szring (oil) Short s%rirg (oil) Short szring (oil) Short s%ring (oil) To be : ' -ed by dual futur= =~= :redux-ion if recurred. Long s/ri:-.g (oil) Long s* '."1 ::g ( o f~ ) Long s'ri:.g (oi!) UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D Page NO.i LEASE Trading Bay State V~ELL NO. A-2 FIELD. Trading Bay Field DATE E.T.D. DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS 3/20/69 23 Checked pressure in 9-5/8" x 13'3/8" annulus. Shut in pressure, 255 psi, bled to 0 psi. Build up to 200 psi in 12 hrs. 9-5/8" x 13-3/8" annulus, 200 psi.. 9-5/8" x tubing, 1425 psi. Connected Halliburton unit to well & pressured 9-5/8" x 13-3/8" annulus to 700 psi, broke to 200 psi. Pumped 40 ft3/min @ 1500 psi. Mixed & pumped 50 sx BJ Gyp-Seal into annulus w/max press of 800 psi. Five minute shut in pressure, 0 psi. CIP @ 5:30 pm 3/23/69. 9-5/8" x tubing annular pressure remained constant 1425# indicating no communication with 9-5/8" csg. Union Oil Compan~ California 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Telephone (907) 277-1401 union 'January 4, 1968 Mr. Thomas R. Marshall, Jr. State Petroleum Supervisor Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Dear Mr. Marshall: Enclosed for your information is the 4-Point Test for Trading Bay State A2-S. Should you require further information, please advise. truly yours, R. C. Har tmann Area Production Superintendent RCH:mgl Enclosure RECEIVED ,t N .,,-. DIVi,,~ION OF MINES & MINERALS ANCHORAGE FORM 401-ANC-W (8/67) C.' ~,"WHITE · Sales and Service V. ng. Dept. K-2, ~201 SUB-SURFACE SURVEY P DU¢ 0N TroT W/ 12 HOUR BUILD UP RECEIVED OlViSiON o~ ~lN~S ~ ~N~^~S ANCHORAGE Company .....U..~o..n. Oi! .0...0.m~ ......... Field. ~ounty ...... C.0.0k..!..r~.t. ...................... State Mono Pod Alaska ............ Lease and Well Sta.te No. ....... A-2 Short .................... Date.. October 19.-..20.,~..'L..9..6..7. ......... Well Shut In: 4:15 A.M., 10-20-67 O~epth (ft) T.H. 4585 4585 4585 4585 4585 T.D .............................................. : ........ Formation .................. ' ............ Elevation .,..Casing ..... : ...................................................... Per[oration .................................................. Tubing: ' Datum Point .... 4~...8.~.', ' -.. Time (hrs)_ Extension (in) Pressure (~si~_ Remarks 10:30 A.M., 10-19-67 Well Shut In , 0.939 2353 1:30 P.M., 10-19-67, On bottom with well shut in 0.937 10 0.937 2348 1:30 to 2:30 P.M., On production for 1 la". on 4/64" choke. Well froze off. Rigged up methanol pump. 11:30 P.M., 10-19-67, On production on 4/64" choke O. 927 ,0~, =_,-2323 11:30 P.M. to 12:45 A.M., On production on 4/64" choke @ rate of 245 MCFD 12:45 A.M. to 1:O0 A.M., 10-20-67, changing choke size O. 921 /~.: 2307__ 1:00 to 1:45 A.M., 10-20-67, On production on 6/64" choke @ rate of 502 MCFD 1:45 to 2:00 A.M., 10-20-67, changing chokes · /9~a 2290 0 91/+ : 2:00 to 2:45 A.M., On production on 8/64" choke @ rate of 752 MCFD 15¼ · ,..,e,.J-- m · 0.906 4 : 2269 2:45 to 3:15 A.M., changing chokes 3:15 to 4:15 A.M., On production on 9!~64'' choke @ rate of 994 MCFD Comparkv: Union Oil Company Field: Mono Pod HOUR 4 POINT PRODUCTION TEST W/ 12 HOUR BUILD UP Lease and Well: Date: State No. A-2 Short October 19-20, 1967 ~Deoth (ft)~ ?ime (hfs) -- ~ExtenSi0.n O. 906 4585 423¼ o . 936 4585 27¼ 0.9365 0.9365 ~es, sure. 2269 Remarks '4:15 A.M. Shut well in 'for 12 hr. Bu./2.d Up 4:15 to 5:15 A.M. Well shut in for 1 hour 5:15 to 8:15 A.M. Well shut in for 4 hours 2345~ ' 2346 8:15 A.M. to 12:15 P.M. Well shut in for 8 hours 12:15 P.M. to 4:15 P.M., 10-20-67, Well shut in 12 hours 4:30 P.M., 10-20-67, Off Bottom Remarks: 1. Temperature at 4585' = 122oF. RECEIVED' DIVISION OF' MINES & MINERAL% ANCHORAGE. Page 2 of 2 /~,RESSURE (psig) GAS ', .AL OPEN FLOW POTENTIAL TEST R, .)RT 4-POINT TEST Test Initial [~ Annual D Special Test Date 10-19-67 Vv' e 11 No. Field j Reservoir Trading Bay M~ddl~ Operator j Lease Union 0il Co. APL 18731 A~_C Ke~t Monopod Platfo~ Dec. 6. 19~6 6669~D 1~0' .... LD. Set C~ ~BG. J CSG. Temperature 'Temperature 135 'F 'F 19 518 40 & 43.5~ ! 6,5A6' . J Leligth-~(L)- ' Rati~ M~F'~'Bbl.'~' I, iquid (Apt) 2 7/8 6.4~ 2 7/8 2,442 1459~ ,, . 760 15920 Pipeline Connection J Type Taps Gas line to West Foreland 0flshore'~Site J ' 0rifiCe:FittinE Multiple Completion (Dual or Triple) Type production from each zone Dual 0il Deep~one- Gas-Sh~llovtona OBSERVED DAT~ , Flow Data (Square ROOt ~ime (Prover) ~~ ~ -' <-.Press. -~- .; Dtff, ~,~;. :. Tubing: ~ C~sin~ -..~ .. Flpwin~ Xo. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size psis. w 'Psl~ . -- 2066 -- ~n. .... 2. 3/4 . .. 2 x 1.25" 6.2 5.2 ~nl q -- . . . 6. 4,8' .... 2002 ~. 1 ] 2 x 1.50" 6.60 6.15 '1~80 FLOIV CALCULATIONS Flow Temp. Gravity Compress. Coeffi- ~/ Factor Factor Factor Rate of Flow LIo. cient h p Pressure F F F Q 1V~CF/D (24 Hr.)V w m psia t g ~ ;'-.~i. 'pr; :.~:'/': ,, · ,; 9,491 25.00 1.0168 1.1471 i.0043 .. '245 2. '.15,583 32.24 1.0419 "I',117I'~ "' ~'"~'~'~':~1~:0043'-~ - ~ 502 .. ~. 24 ~483 30.72 1. 0518 1,1471~_ :.~ ~.1'0013 752 2~483 40.59 ~.~47~ 4. PRESSCRE CALCULATIONS P P Cal. w w p., F Q (F Q): (F Q)2 X 1-e-s Pe pe -- p~ p · p (ps(a) :t c c c %v .m c.,,,. .....: lar , .;.. . .... -.:w ,; -P · C t l. /-' ; ;"~' "~ "' ':~ ;'~' ' 2. .~. -'-.'f.'~ ': . . '. :.'-v,!' ;-~; '.-:' '...; -,- -,i , .,,~ ,, · , i Ahsolute Potential j n CERTIFICATE: I, the ~dersi~ed, state Lhat I am the of ~e (company), and ~at I am author~ed by s~d comply t0 make this report; and that ~is report was pre- pared ~der my supervision and d~ection and that ~e facts stated there~ are true, correct ~d complete to ~e best of my ~owledge. RECEIVED DI¥~$~ON OF M~N~ & ANCHORAGE Alaska Oil and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4.Point Test) Form No. G-1 Authorized by Order Ho. I Effective October 1, 1958 i 10; 8 7 8 ~2 1 RECEIVED DIVISION OF 'MINES ., ANCHOP~GE / 6 7 8910 8910 ................"~-"'" i '(-' .... :'::" .... "': '~ ...... '-":~;:'~'*~ ~ ..... ~ :'"-'"'~ '" 'i~, I FORM 369 4-63 UNION OIL COMPAN~"~xOF CA/LIFORNIA ,-~ Document : nsm:ttal ~., October 16, 1967 :" .'-.:. '.'.::. TO State of Alaska AT Anchorage RECEIVED FROM Union Oil Co. Oc? 7 aT Anchorage TRANSMITTING THE FOLLOWING: ................................... ' ~'11 i'~iP '~ · ' ,wo.,o~.(~ :':;;-'~.s [JNION TRADING BAY STATE A-2- 1 Nell History (Drilling Report) No. Trading Bay State A-2 Trading Bay Kenai Borough (cou~T~;) UNION OiL C, Ob4PANY DRILLING REPORT RECEIVED- ...... ~,~ u~ MINEs & MINE~ Rotary (TOOLS ) (PERIOD ENDING) {NOTE INEFFECTIVE CASING) DEPTHS ' ' ........ '' J~==-"'~ -- FROM I TO I DEPTH J ANGLE Jl DATE ---- ' ' ' J'CORRE'~ J . DETAILS OF OPERATIONS, DESCRIPTIONS, AND RESULTS Oc~. NOTE MAKE 0]' INSTRUMEN3 17 Moved. Rig from Trading Bay State A-1 (conductor #21) · to Trading Bay State A-2 (conductor #28.) " St~teA-2 Measurements . .-' . Water depth = 62' MLLW Rotary Table to Ocean Floor = 174' .. Rotary Table to MLLW = 112' Rotary Table to Drilling Deck = 22'.07' Drilling Deck to Production Deck = 18.75' Rotary Table to Production Deck ' 40.82! 18 0 792 190' Vertical Spudded 12 1/4" hole at 3:00 A.M. 10/18/66. Drilled 292' " 12 1/4" hole to 385'. Pull out of hole. Picked up 385' 0~15'' 2 cone bit and Giliigan drilled to 739' Pull out of S-55-W hole. Picked up Tri-cone bit, Monel D.C. and drilltrols drilled to 792'. Mud Wt. 78#, Vis. 61, W.L. 6, Sd. 6%, Cake 2/32 PH,9 See directional plot for surveys. 19 792 1048 Continued drilling 12 1/4" hole to 1048'. Pull out of hole - picked up 18 5/8" security hole opener. Unable to go below 227'. Ordered out mill to open pile Joint. · Mud Wt. 78#, Vis. 48 20 ~ Ran 17 1/2" Sec. hole opener - opened 12 1/4" hole to 17 1/2" from 227' to 1046'. Mud Wt. 73# Vis. 67, W.L. 12, Sd. 2%,,Cake 3/32 PH.8 21 M~de wiper =un with 17 1/2" H.O. Circulated and Conditinn- ed hole for 13 3/8" casing. Ran 23 joints 13 3/8,1'' 61#_3~55.w~th BRttreB.s_~ & C .and landed same 37.82' below rotary table with Baker Guide i Shoe at 1023' (849' below ocean floor) and Baker Flex i ~ Fil!up Col~r at_ 982.02'. Finned cenL~Ka!izin~ ,pup.~j~int .~ - pn ~op. Cemented. ~i~h 950 sac.ks _co.nstr~t.~on. ceme.nt~ mixed with seawater. Good returns th~:ou~hout with ~ood · returns to surf.~qe..~ Cem~nt~.in ~laceS:Jq 1.?!,.,.~0/~!/6~. 22 1048 t060~/ Flanged up and tested B.O.E. Tested lower casing head, t blind rams, pipe rams and hydrill with 1500 PSI - O.K. Dri].led out cement and shoe - 950' to 1023' Drilled 2 2 INC. T OU '~ 14- DIVISION ENGINEER " 'OCT i ? tcJei '. DIVISION OF MINES & MINEEAI. J DRILLING REPORT Rotary (TOOLS J (PERIOD ENDING) 13 3/8" 61 J-55 = 1023r 12 1/4" hole. {NOTE; INEFFECTIVE CA.~ING) WELL NO. Trading Bay State A~2. Trading Bay (FIEL0J Kenai Borough sec. 4 T. 9N m. 13W ',YOURS DEPTHS INC L IN A T ION PROM TO DEPTH ANGLE .... J - NOTE MAKE Ol INSTRUMEN1 1048 1060 1060 '1614 · . · 1614 2332 2332 2895 2895 3271 3271 3533 3533 4123 4123 4475 · DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS 12 1/4" hole from 1048' to 1060' Directional drilled 12 1/4" hole from 1060' to 1614' using Dynadrill from 1118' to 1362' to turn hole. Mud Wt. 74#, Vis. 52, W.L. 8 cc. Sd 1 1/2% Cake 2/32 PH 9 Directional drilled 12 1/4" hole 1998'. Pulled out of hole for bit and drilling assembly change. Replaced bottom stabilizer sleeve with 11 1/2" sleeve in attempt to drop angle. Continued drilling 12 1/4" hole to 2332' Pulled out of hole for drilling assembly change. Mud: Wt. 75#, Vis. 50 W.L.'7.5 Sd. 2 1/2%, Ck 2/32 PH.9 Continued drilling directional hole to 2895' with bit and drilling assembly change at 2801'. Down 2 1/2 hours due to po~er failure. Mud 76#, Vis. 48, W.L. 6, Sd. 2%, Cake 2/32 Ph. 9 Drilled 12 1/4" hole to 3094' at this time it was discovered that a large volume of water had been injected into the mud system by mistake, necessitating the shut down of drilling operations so mud could be conditioned. Drilled ahead to 3178'. At this point, electric control panel on drm~,orks shorted out and burned all control lines to drilling equipment. Repaired same - circulated hole-pipe free. Continued drilling 12 1/4" hole to 3271'. Started out of hole for bit change. Mud: Wt. 76 Vis. 50 W.L. 6 Sd. 1 3/4%, Cake 2/32 PH. 9 Driiled't2 1/4" hole to 3456'. Drilled with dynadrill to 3533' Mud Wt..76.5~Y Vis. 56, W.L. 6, C. 2/32 PH.9.5 0±1 4% Continued drilling 12 1/4" hole ~to 3958' Pulled out of hole for bit and drilling assembly change. Replaced 11 1/2" stabilizer on top of Monel, with a 11 1/4". Repaired electrical cable to Rotary Table. Continued drilling 12 1/4" hole to 4123' Mud Wt. 79.5, Vis 44 W.L. 4 Sd. 2% C-2/32 Ph. 9.5 0il 4% Continued drilling 12 1/4" hole to 4180'. Pulled out of hole for bit change. Ran back in hole-drilled to 4316' Pulled out.of hole for bit and drilling assembly chance. DIVISION ~.NG IN F-. E,R Wm~L NO.Trading Bay State A-2 Trading Bay [FIEL-D J Kenai Borough {COUiqfY) sec. 4 T.__gN ~. 13W rS.,M. 13 3/8" 61 J-55 = 1023' 12 1/4" hole ~NOTC IN£F'F£CTIV~ CAE, lNG) Rotary {TOOLS} [PERIOD :,lO. T UR$ DEPTHS .... ico~c¥' FRO~ j TO DEPTH j - NOT£ MAK~ OF INSTRU~ENI · 4123 4475, I · · 4475 4624 .4624 4639 . · · 4639 4864~ 4864 5044 5044 5120 5120 -5120 .. ., · · __ _ -- _ DETAILS OF' OPERATIONS, DESCRIPTIONS AND RESULTS Laid down top 12 1/4'! Serco Stabilizer, picked up new bit and ran back to bottom. Continued drilling to 4475'. Picked up angle but hole turned to the right. Mud Wt. 79#, Vis. 46, W.L. 5, Sd. 1 1/2%, Ck. 2/32, PH.9 Oil 4% Drilled 12 1/4" to 4592'. Pulled out of hole for bit change and to pick up Dynadrill. Using the dynadrill continued drilling' 12 1/4" hole to 4624'. Mud Wt. 79~/, Vis. 46, W.L. 5, PH. 9 Cake 2/32 Oil Continued drilling 12 1/4" hole, using the Dynadrill, to 4639'. Pulled out of hole.Due to 65 knot winds, unable to go back in hole. Schlumberger ran I.E.S. Log from 4639 to 1023' .Ran Mud Wt. 79, Vis. 46, W.L. 5, Ph. 9, Cake 2/32, Oil 4%. · Laid down tools. Picked up bit and drilling assembly. Drilled 12 1/4" hole to 4864' with bit change at 4809'. Mud Wt. 79#, Vis. 45, W.L. 5 cc. Sand 1 1/2%, Cake 2/32 Ph. 9, Oil 4%. Drilled 12 1/4" hole to 4878. Pulled out of hole for bit change. Continued drilled 12 1/4" hole to 5029'. Pulled out of hole, changed bits and picked up Dynadrill. Drilled 12 1/4" hole, using Dynadrill, at 5044'. Mud Wt. 79f/, Vis. 43, W.L. 5, F.C. 2/32, Ph. 9, Oil 5% Drilled' 12 1/4" hole, using Dynadriii, to 5120'. Pulled out of hole' for drilling assembly change. Left 12 1/4" bit, 7 1/2" x 2' bit sub and bottom Section of Dynadril! in hole. 'Dynadrill parted at lower b'earing housing~ Ran 9 3/8" Bowen overshot and recovered all of the fish with the ·exception of the bearing and the 6 5/8" x 6" skirt. Ran in hole with bit #14 R.R. Circulated and conditioned mud while working on junk. Pulled out of hole. Picked up 9 3/8" Globe Junk Basket. ~Ran same-cored from 5120- 5121' Pulled out of hole. No recovery. Picked up original drilling assembly and Junk sub. Ran in hole - Reamed from 5041 - 5120. Mud Wt. 8!// Vis 48 WA 6 Sd 2% FC 2/32 Ph.9 Oil 4% ! D|Vi$1ON ENGINEER UNION OiL COMPANY ~zuu NO. Trading. Bay State A-2 Trading Ba~F' · ' ~'~D~ Kenai Borough (COUNTY) sec. 4 ... 9N. ~. 13W ~. DRILLING REPORT Rot ary (TOOL5) (PERIOD ENDING) OCT 17 1967' DIVISION OF MINES &, MINEItA~ ,I~I~"~ OR D _--!3--3~i a-55 = i-o-2-Y' [NOTE INEFFECTIVE CASING) IqO. DEPTHS INCLINATION. ~OV, NOTE 1,4AK£ O INSTRUMENT) . 2 5 5120 5229 Drilled 12 1/4" hole to 5144'. Pulled out of hole for n~w bit. Ran in hole - reamed from 5120' to 5].44'. Had some trouble with junk sticking pipe. Worked around junk and . drilled ahead to 5229'. Pulled out of hole for bit change~ Recovered one large piece of junk 1 1/8"' x 1 1/4" x 3/4", with junk sub. ~ Mud Wt. 80 Vis 52 W.L. 6 Sd 2% F.C. 2/32 P.H. 10.5 Oil 4% 2. 6 5229 5368 ~Drilled 12 1/4" hole~ to 5368'. Pulled out of hole for bit and drilling assembly change. Left one 12 1/4" driltrol ~ blade in hole. When coming out of hole lifting nipple parted dropping 3 Stands of drill collars and tools. Stabilizer caught in rotary 'table, preventing collars from going to bottom. Broke and checked all connections. Replaced Servco Stabilizer sleeves, going in hole with bit. Mud Wt. 81 Vis 46 W.L. 5.4 Sd 2 1/4% F.C. 2/32 PH 10.5 Oil 7% 2 7 5368 ~5557 Drilled' 12 1/4" hole to 5557'. Pulled out of hole becausa of~loss in pump pressure, to check for wash out. Mud Wt. 80.5 Vis 48 W.L. 5.3 Sd 2 1/2% F.C. 2/32 Ptt 10.5 Oil 6% 2 8 5557 5672 Pulled out of hole. Found drill collar pin cracked and washed. Laid down both bottom Spiril Collars and replaced with new ones. Laid down Junk sub and picked up Shaffer Dampening Sub/ Ran back in hole. Drilled ahead to 5672' with a bit change at 5662. Changed sleeves on the two bottom Servco Stabilizers. Mud Wt. 79.5 Vis 45 W.L. 5.3 Sd 2% FC 2/32 PtIO 10.5 Oil 6% 2 9 5672 5892 Drilled 12 1/4" hole to 5795'. Pulled out of hole for bit change i~Repaired Gear Selector on Drawworks. Ran in hole. and dri'lled from 5795' to 5892'. Mud Wt 80 Vis 42 W.L. 5 Sd 1% FC ~/32 PH 10.5 2100f~ Oil 5% · 2 10 5892 600,6' Drilled" from '5892 to 5979'. Pulled out of hole picked up " ' core barrel and jars. Ran in hole with 2 std~.~ 7 1/4" ¢~r~e f~! 5979' 6006' cut 27' recov27' DC's and Christensen C. Head ~1. Cir. to bottom. Cored t Core !~! from 5979' to 6006'. Pulled out of hole. Recovered · , 27' core. Laid down C.B. and jars. Ran in hole with bit i Mud Wt. 80 Vis 47 W.L. 5.2 Sd 1% FC 2/32 PH 10 2100~) Oil 6,% · DIVISION ENCIN~[~ - .:-,r- ~4 1,53 . . t,'.:.;~_LNO. Trading Bay State A-2 '~.' ~ding Bay · ~" nai Borough. ..... ,~C OUNT Y') UNION OiL COMPANY DRILLING REPORT Rot ary . (TooLs ) (PERIOD ENDING) DIVISION OF MINES & MINEIAt, I, CASING RL~CORD ~ 13 3/8" 61~/ ,T 55 = 1023' NC.J t DATE ~TOU~.,. 1966 2 i 11 2' 12 ~ 13 2 14 2 15 2 16 17 DEPTH~ FROM TO 6006 6198 6198 6261 6261 6371 6371 6418 6418 6538 6538 6669 6669 TD INCLINATION DEPTH CORRECT ANGLE DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS Opened. C.H. from 5979' to 6006' and drilled from 6006' to 6198. Mud Wt. 78 Vis 42 W.L. 5~2 Sd 1% FC 2/32 PH 10 2100# Oil 6% Pul%ed out of hole. Lost bearings out of 2 cones. Ran in hole; with bit and junk sub. Drilled from 6198' to 6256'. Pulled out of Hole, recovered 1/2 of bearings. Drilled from 6256' to 6261'. Pulled out'of hole, recovered a few bearings. Picked up C. B.. Now running in hole. Mud'wt. 78.Vis 45 W.L. 5 Sd 1% FC 2/32 PH l0 2100# Oil 6% Cut Core #2 from 6261'-627~'. Core barrel jammed. Pulled out of hole Recovered 7' core. Core head O-Ringed. Ran in hole with bit. Reamed C.H. from 6261'-6273'. Drilled from 6273' to 6371'. Mud wt. 78 Vis 43 W.L. 5.3 Sd 1.'1/4% FC 2/32 PH 10 2100# Oil 6% '. Pulled out of hole. Picked up C.B. Ran in hole and cut Core #3 from 6371' to 6380'. Core barrel jammed. Pulled out of hole. Recovered 9' core. Ran in hole and opened core hole from 6371' to 6380'. Drilled from 6380' to o~18' Mud Wt. 78 Vis 44 W.L. 5.4 Sd 1 1/4% F.C. 2/32 PH 10 2100# Oil 6%. Drilled 6418 to 6538. MUd Wt 78, Vis 43 W.L. 6.4 Sd 1 1/2% FC 2/32 PH 9.5 2100# Oil 5% Drilled 6538-' to 6669". Circulate out samples, made short trip, circulate and condition hole to log. Started out of hole and lost 239.14' .of tools 27 stand off bottom. Servco Pin had broken off of top of steel drill collars. Fish in hole consist of 6-7 1/4" DCs, 2 Monel DCs, Shock sub, 2 stabilizers and subs. ~ud Wt 78 Vis 55 W.L. 4.8 Sd 2% FC 2/32 PH 9.5 Oil 4% PP 2100 Recovered all of fish. Ran in hole with bit and reamed from 6280 to TD - had 20' of solid fill in hole. Circulate and condition mud to run logs. Mud 79, Vis 55 W.L. 4.2 Sd 2% FC 2/32 PH 9.5 Oil 5% PP 1100 , .. F~ORIv~ I~3 {REV UNION OIL GOM~ANY .... ~-"---"~' ,',,~0:) ' · . jot,'~x: OCT 17 1967 DIVISION OF MINES & MINEEAI~ C/:k~J NG WELL NO. Trading Bay State A-2 TradinA Bay Kenai Borough DRILLING REPORT Rotary , (TOOLS ) 20" conductor - 227" 13 3/8" 61# J = 1023' 9 5/8" 40# 43.5# J-55 N-80 SEC. /4 T. qM ". 13W '~'~. C 645.6 DV-.__3903 - {PERIOD ENDING) {NOTE INEFFECTIVE CASING) DEPTHS : J INC LINiTION 7:O, DATE I DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS CORRECT To,oRs 1966 I ' I ~OTE MAKE OI INSTRUMENT~) ~OV. ~ 2 18 6'669 TD Pulled out of hole and ran Schlumberger Logs. Ran dual · induction, Gamma Ray -'Density, IES and Sonic Logs. i. 2 19 6669 TD Continued running logs. Dipmeter tool failed and hole · i' was getting sticky. Made tripin hole to condition same, i ,/ Pulled out of hole and ran dipmeter and started taking sid~ : wall cores. 2 20 6669 TD Finished running sidewall cores. Rigged do:~ Schlumberger ~ Ran in hole with bit circulated and conditioned hole for · casing. Pulled out of hole, laid down Servco Stabilizers i and Monels. Rigged up and started running 9 5/8" casing. Mud Wt. 79, Vis 53 W.L. 4.2'Sd 2% FC 2/32 PH 9 Oil 6% ' 2 21 6669 TD ~an 155 jo.ints of 9 5/8" casing. Landed at 6546.29 KB · Shoe at 6546.29 - F.C. at 6.461.90.' - D.V.. Collar at 3-~0--3-~03~' ' Ran 5 centralizers every other joint from 6546' to 4700' Cemented in two stages as follows: 1st stage - from 6;46 to 3903 with 1150 sacks. Pumped plug ~ with 1500# psi. Cement mixed with seawater. Cement in place 4:45 A.M. 11/21/66. Opened D.V. tool 2nd Stage - from 3903 to 1200''with 1080 sacks mixed with seawater. Displaced and closed D.V. Collar with 2500 psi. Cement in place at 7:30 A.M. 11/21/66. Set slips on 9 5/8" casin · Installed 10" 3000# Shaffer Tubing Head. Tested tubing~ · head wi~ 3000#~for 1/2 hour. Casing record from bottom: ' 6546.29 - 6544.30 Shoe 6544.30 - 6463.94 9 5/8" 43.5# N-80 T&C Buttress 2 joints ' - 6463.94 - 6461.90. Float Collar.. ~ 6461.90 - 5400..79 9 5/8" 43.5# N-80 T&C Buttress : ~ 25 joints : 5400.79 - 3905.21 9 5/8, 40# N-80 T&C Buttress.~ ~ 36;Joints i 3905.21 - 3903.03 Halliburton DV Stage Collar ~ 3903.03 - 3313.61 9'5/8" 40# N-80 T & C Buttress ~ _ 14 joints ! - 3313.61 - 74.01 9 5/8,,-40# j-55 T&C ButtreSs i 76 joints : ' '74.01 - 34.05 9 5/8" 43.5# N-80 T&C Buttress ~ 34.05- '0 Landed 34.05 below zero · / DIVISION ENGINEER 1 W,~LL NO, i Trading Bay State A=2 Trading Bay ~E ~D J Kenai Borough · sec.. 4 T. .9N -.. 13W S~.~M. UNION OiL. COMPANY DRILLING REPORT DIVISION OF MINES & MINE 20" co~ducto~ 227' ~3 3/8""6~f/ ~-55 C1023' 9 5/8" 40f/ 43.5// J-55 & N-80 C 6456 --{TOO~7) D~V--3-90.3 (PERIOD ENDING) {NOTE INEFFECTIVE CASING) DEPTHS J. INCLINATION' DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS .o. DATE ...... i co~ECT TOU~S 1966 FRO~ I TO DEPTH AN~LE Nov. 2 22 6669 TD Tested blind rams ~nd 9 5/8" casing with 1500#. Ran in hol, .'.6461 P.B.T.D. Iwith 8 5/8" bit and located top of DV collar at 3894'. ~Drilled plugs and cemented to 3903'. Ran bit on in hole ! and tagged top of cement at 6415' and drilled out to 6461'. · ' Rigged up and ran Gamma Ray and CLL log from 1200 to 6463' ' and cement bond log from 1200' to 6458'. Schlumberger 2 23 6669 TD measurement Perforated from 6090' - 6091.5' and squeezed 6461 PBTD cemented perforations as follows: B.D.F. with 3000 p~i at 2 CFM,.pumped 30 CF seawater .. ahead, mixed 50 sacks cement with seawater to 114# slurry Pumped cement with 500 CF mud at 1500 psi with tool open, ~ closed tool. Pressured 9'5/8"~end--DP annulus to 1700#, , continued displacing with pressures to 4200 psi. Pressur~ ! BDF and when tool cleared pressure d~z~pp~dto 2000 psi. I . Staged 37 CF over 50 minutes period to FP of 3600#, . ; pressure held o.k. Total 652 CF. Ble~ back 7. CF Cement in place 10:20 A.M. 11/23/66 with 20 sacks squeezed into formation. Ran in hole with bit and tagged, cement at'5988' and drill. i out to 6050' Lost all fire pumps on platform,waiting on i divers to check on seawater wells for fire pumps,while · ~ waiting on cement. 2 24 6669 TD 'Waiting on divers and assisting divers, Ran fire pumps. ! PBTD 6050' Finished ~ 2 25' 6669 TD hooking up fire pump No. 2. Rigged up Schlumberge PBTD 6050' and perforated 9 5/8" casing from 5830' - 5835' with 2 1/2" : : jet holes per foot. Ran HOWCO packer and set at 5808' for DST #1' OPened tool for 12 minutes and closed for ICIP for : , 1 hour 31 minutes. Opened tool at 11:57 A.M. for 8 hours · produ'qtion test. Gas to surface in 38 minutes. Closed tool at'7:17 P.M. for 2 1/2." final .build up pressure. ~ I Back scuttled during pressure build-up.· Recovered 18 I barrels water cushion and 2 barrels gas cut mud. Pulled ou ! ~ ] . , of hole Temperature 123~F. ' , Pressure record: Above Pkr. Belo~ Pkr. ~ IHP ' 3120 ,, 3140 I . IFP 419 439 FFP 419 , 439 ICIP 2196 2208 / °~ - ' ~ DIVISION [NGINE, L-~R / ~ORM ~ m~v~/~2~ ~Vi~ION OF MINES & MINE~ UN]ON OIL. ~OMPANY WELL NO, ~a~ ~a~ State A-2 .-- ?0" ~~r Trading B.ay DRILLING REPORT ~ ~/R" ~]lL&-35_~23' ~, .... 9 5/8" Rot ary C .6.4&~ Kenai Borough 13W · ~c. 4 T. 9N ,. ~. (PERIOD ENDING) (NOTE INEFFECTIVE DEPTHS t INCLINATION NO. DATE --- "' · j J CORRECT DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS TOURS 1966 FRO. i TOI OEPTNI ANGLE ~ , , ~OV NOTE MAKE O" INSTRUmeNT ' ' 2 25 6669 TD Pressure Record: (Con't) PBTD 6050' Above ?kr. Below Pkr. SFP 419 439 SFFS 441 461 FCIP 1449 1469 FHP 3120 3137 . ./ 2 '26 6669 TD Pulled DST tools, ran in hole with open end drill pipe 0BTD 6050' ~ and conditioned mud. Rigged up Schlumberger and perfor- ated from 6020' to 5990', 5960'-5900'. , 5850'-5820' with 4 1/2" jets per foot. 2 27 6669 TD Rigged down Schlumberger, picked wp }tOWCO tester for PBTD 6050' DST #2. Set packer at 5779' with tail to 5795' with 500' WC, opened tool at 0634 hour, strong blow - closed at 0639 for 1 1/2 hours. ICIP - continued to blow through DP with gas to surface in 10 minutes. Opened tool for produCtiSn test at 0809 hours, Water cushion to surface, . shut in tool at 0815 hours. Opened tool at 0840 hours. SI at 0843 hours to switch well through, seperator, with 1950psi surface pressure. Opened well to trap at 0857 hours. At 0905 hours surface pressure 1890 psi on 1/4" choke. Bled off to 1775 psi at 1337 hours. Gas rate 1775 MCF per day. Changed choke to 3/8" at 1352 hours with 4000 MCF/Rate. S.I. at 1448 hours to change to gross · s~perator. Opened at 2038 hours through 1/4" choke. · · 1700 psi surface pressure and 1600 MCF per day rate. .At 2046 hours changed choke to 3/8" rate 4730 MCF per day. Open 2 hours 52 minutes, closed tool at 2330 ho~rs. Total ! time 20 hours 26 minutes. Reversed circulated and re- covered 10 barrels gassy muddy oil - 40" API gravity. Pressure Record: , .' - Above ~kr. below pkr. f IHP. 3073 3090 IFP 1502 2371 ~ ICIP 2584 2595 FFP 1272 2110 FCIP 2573. 2610 FHP 3061 3079 Temp. 1270F ' 2 28 6669, TD Laid down test tools. Ran in hole with 8 5/8" bit and PBTD I 6461' casing scraper. Drilled cement from 6050''to 60~0'. Cir- ~ .t ' cula~ed and comdi~ionad mud and built mud weight ~o 7~~ L'. _ -__ ~ " . ,_ ..... _ ........... FORM 1~3 (REV 5/62) OCT 1.? 1961 ,,. DIVISION OF MINE5 & MINEIJAi~ W[LL NO.. Trading Bay State A-2 Trading Bay (FIELD J Kenai Borough (cOuNTY} · 4 9N 13W $EC .__T. __R. I~ & M. UN]ON O!L C OMPA."! Y D ' ' RE R,L,_ING PORT Rotary (TOOLS;) (PERIOD ENDING) .. {NOTE INEFFECTIVE CASING) DEPTHS INC LINA T ION NO. DATE ...... '" CORRECT DETAILS OF OPERATIONS,. DESCRIP 'OURS 1966 FROM J TO DEPTH ANGLE ] NOV. NOTE MAK[ OI INSTRUMZN%) 2 29 6669 TD Rigged up Schlumberger and perfor PBTD 6461 follows with 4-1/2" jet holes par 6420 to 6300 (120') '6285'to 6150 (135') 6140 to 6110 (30') Total 285' Ran in hole with bit and scraper to make inhibited Nag1 water for 2 30 6669 TD I Circulate and condition mud - rai out of hole Rig up'to run tubing tubing. Started in hole with D.P. Dec. 2 1 6669 TD Finished going in hole with DP, C PBTD 6461 mud, Pulled out of hole, rigged u tubing.in 30 ~H winds. 2 i 2 6669 TD Running and Hydrotesting dual tub PBTD 6461 shut dm.m due to high winds. 2 3 6669 TD Waiting on winds to subside - run PBTD 6461 . 2 4 6669 TD Finished picking up tubing string PBTD 6461 in tubing spool with great diffic not seal prpperly. . 2 5 6669 TD Landed dual tubing strings as fol PBTD 6461 Lonz Strinzs: Ran and landed 6110 N-80, 8 RD, EUE tubing with baker at 6040' and with Baker Model "A" ' and Otis Ball Valve at 291'. ' Short,,Strin~: Ran and landed 2 7 EUE at 45~5' with Otis Ball Valve i'Tested Otis Valve Control lines t Shaffer dual Christmas tree and t Displaced mud with inhibited sodi' chloride water and displaced tubi " fuel. Dropped ball and set lower 2500 psi'pump pressure. Set uppe 3000 psi pump pressure. Tested tu ~ 2000 psi. Had communication tryi · Inserted OtiS ball valve dummy an, O.K. Preparing to flow wells. "IONS AND RESULTS :ed Hemlock Zone as foot: while waiting on material )acker fluid. :ed mud to 78#. Pulled - too windy to run Circulate and condition ~ and started picking up .g strings in high winds-. g dual tubing string. s. Attempted to land szma y. Shaffer Donut did )WS: ' 2 7/8" O.D., 6.5#, Model "E" single packer Dual Packer at 4585' ~8" O.D., 6.5#, N-80, 8RD, at 260'. 5000 psi. NiPpled uo :ested same to 3000 psi. chloride and calcium g strings with diesel packer (Xodel E) with packer O[odel A) with ing - casing annulus at to test lower packer. tested lower packer - ','.ELL NO. Trading Bay State A-2 Trading Bay Kenai Borough (COUNTY) sec. 4 T. 9N .. 13W : .... 0Cl 1 ? 19'6'/ UNION OIL C:OMPAN Y DRILLING REPORT Rotary (TOOLS) DIVISION OF MINES & MINERALS 20'' conductor 227' 13 3/8".C 9 5_~8" c 6456 - DV 3903 Perf. Squeeze 6090-6091.5 Perf. 5820-6420 at intervals {NOTE INEFFECTIVE CASING} (PERIOD ENDING) DE PTH$ INC LIN A T ION C6~RECT-I DETAILS OF oPERATIONS, DESCRIPTIONS AND RESULTS NO. DATE -- i TO DEPTH I ANGLE TouRs 1966 FRO~ , , DeC .OT~ ~A~E O~ INSTRU~.~) 2 6 TD 6669' PBTD 6461' Attempted to flow (Hemlock) long string with no success. · . Opened short tubing string (Gas Zone) to separator at approximately 0630 hours, and well began to flow. Cleaned up ~hrough separator. Flowed at approximately 4.5P~CF per ,..- day rate on 22/64 choke. Shut in with 2150 psi tubing ~ pressure. Attempted to rock long string tubing with ~ short string gas. Rigged up to swab long string to 300', i' could not get'below. Otis Ball Valves ~ondrel. Attempted to rock long string again withoht success. Ran in and opened side door sleeve in long strin~ below upper packer at 4600' and unloaded long string with gas from upper gas zones. 2 7 6669 TD Production testing - long string unloaded diesel and water ~' PBTD 6461 but no follow through. Started in hole with piano wire ~ tools to open sleeve and noticed fluid rise to 240'. i Pulled a~d laid down wire line tools - turned well into ! test seperator- wall began'flowing at 12:30 A.M. 12/7/66. :~ Tested well. Pulled bomb at 7:00 P.M. Ran Otis Ball Valv Opened valve, flowed well, closed valve, bled off tubing - · Valve tested okay. , ~ 1 8 Ran in short string, pulled dummy valve, Set Otis Ball i. Valve. Opened valve, flowed well, closed valve, bled ~ tubing down. Valve tested O.K. Bled both tubing strings to zero - both %elves O.K. · · ' Rig released at 4 A.M. 12/8/66 · · . · {' ' >" ANCHORAG FiLE Bay DRILLING REPORT '(~'OUNTY) (TOOLS) 'c. 4' ~.. 9N ~. 13W S~. IP£RIOD ~NDINg) JNOTIF IN~'FFFCTIVr CA.fi, ING) DEPTHS J INCLINATION FROM TO DEPTH I NOTE MAKE: O C0~"i'~N.C~0R: EOUIPM!NT: LOC~TIIN: ELEVATi '.ONS: ........ MEASUR] :MENTS: CORRECT ANGLE DETAILS OF OPERATIONS, DESCRIPTIONS AND RESULTS CALDRILL ALASKA, INC' OILWELL 860 Conductor No. 28 1613' N. and 570' W. from S. E. corner ~.ec.. 4, T9~i, m. 13W, ~...M. Water Denth = 62' MLLW Rotary Table to MILLW = 112' Rotary Table to Ocean Floor = 174' Rotary Table to Prod. Deck = 40.82' All depths from Rotary Table RE'CEIV , DIVISION OF MINES ~,N(~. oRAGE Union Oil Company of California 507 W. Northern Lights Blvd.{O Anchorage, Alaska 99503 February 14, 1967 Mr. Karl L. Vonderahe Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Dear Mr. Vonderahe: I am enclosing both our Union Oil Company Monthly Well Production Form and the State P-4 Form, as we decided by telephone February 14, 1967. At that time, we decided to let determination of the form you prefer wait until the February report is due, thus giving you a chance to determine which one will be most suitable to your needs. Sincerely, B. N. Evans District Office Manager RHC:jw Encl. (2) FORM 40I-BL (REV. 12/~) RECEIV[D FEB 1,5,1967 DIVISION OF MINES & MINER. Aka ANCHORAGE, Form No. P--4 Effective: July 1, 1904 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE LESSEE'S MONTHLY REPORT OF OPERATIONS TI~e followir~ff is a oorreot report of operations and prod~etioT, (inel~dir~ drilling and prod~zoln~ wells) for th, e month, of ......... J_?__~u__~r__Z .................... 19___6.7__, _ ........................................................................... ./l ~ e r~ t ' s address __5__0__7___~,____N_9__r__t__h__e__r__n.___L__~_g_h_.%_s____B__l__v__d_, .......... C o m p a n y..JJJl ~ o g _ . O ~ _ _ C o m p ~ n ~ _ o f _ _ ~ a J_i. f o r n i a Ph, or~e ...... _2__7__7__-__1_~_0__1__ ............................................................ ~1ger~t' s title I1'I stzicl:__0peral;t.o~z.~anage~: .. SEC. AND CU. FT. ov GAS ~ OF ~ TWP. RANGE WELL DAWS Net (~ALLONS O1~ BAE~m~ oF REMARKS NO. pao~cm~ BARRE~ OF O~ GRAVY (~ tho~) GASO~NE WATER (If (If &llling. depth; If shu~ down, aa~; RECOVERED nono, so s~te) date ~d r~ult of ~t for ~o~e ._ ~/4 o~ 1/~ Sec. 9N ~3 A2 30 24,388 3~.4 9,835 ~C~.~ -- 26 No total "on the beach" ~torage f~gure Bott~>m ~o~ available Location I .... NOTE.--There were ...N.~0. ........................................ runs or sales of oil; .................. NO ........................ M cu. ft. of gas sold; ............................ No .......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be fined in duplicate with the Division of Mines & Minerals by the 6th of the succeeding I~o~ht, ujde~s%o~h~r,~i~e K ~L ~ I V tU~ directed. FEB 1 §,1961 DIVISION OF MINES & MINERAL~ A klt'"MC1 P At"'.l: Form No. P 4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: Suly 1, 1964 LAND DFFI=E ?! / LEASE NUMBER ~,~.~ · LEASE ~R UNIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS T]~e followir~ff is a oorreot report of operatior~s arid. prod~otior~ (i~cl~di~ drilli~ff and prod~ci~ff wells) for t~e mo~tk of ........ ~ ..... ~S.~_~_[_' ........ , 1~___, ............................................................................ ............... ..... .............................. . ....... ~ - ......... -~:--bT-~ff~ ................... ~o~e ....~;~ .......................................... ' .......... ~ .......... z~e~t's title Cu. FT. or GAs GALLONS or BARRELS or REMARKS SEC. AND ~rWP. RANGE WELL Days. BAERELS OF OIL GRAVITY GASOLINE WATER (If (If dd~g, depth; if shut d~n, oa~; ~ or ~ No. raO~O=D (~'thom~) Rxcov~ none, so s~te) ~tz ~d r~ult of ~t for oon~t of g~) , '. . . ~ 9N 13~(' A-2 ) Completed well as &ml co~l~tion. ~ ...... ~'" Completed December ;, 1966. See compl ~tion repo~ted - dated December 19, 1966. . . ANCHORAG8 R:FF~AL3 NOTE.--There were .............. ..~...O. ............................ runs or sales of oil; ........................... ~0. ............... M cu. ft. of gas sold.; ............................................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. .~ 1,6, 1~7 . Mr. It,. D. ~ Form P---~7 15. Oct SUBMIT IN DUPLI~ ~E* ~ STATE OF ALASKA (See ~'~, structions on OIL AND GAS CONSERVATION COMMISSION reverse side) WELL COMPLETION OR RECOMPLETION I~I~ORT AND LOG * la. '~'~ OF W~LL: ........ O~L ~ ~AS b. T~PE OF COMPLE~ON: ' · NEW ~ WORK DEEP- PLUG DIFF. ~ ~ WELL~ OVER ~ EN ~ BACK ~ RESVR. ~ ~.~t~/~ 2. NAME OF OPERATOR ' U~ion 0il Company of Califomia . ~. ADDRE~ OF OPERA~OR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 LQCATION OF WELL (Report location clearly and in accordance with a~ ~tate~ rgqutremen~s)* At su~aee 1613' N., 570' ~, of S.E. corner S~c~On ~ ~ o SM A~ to~ prod. interval re~orted below 387' N, 1352' At total dep~ NO. 456' and W. 1463' · Effective: July 1, 197 5. LEASE 5ESmNaTI0~' ~ND ~ ~O. . · ADL 18731 6. IF INDI~NfALLOTTEE OR TRIBE NAME :: 7.'UNIT AOREEMENT NAME · S. FARM oR. LEASE NAME · 'Trading BaY ,State: 9. WELL NO. · · 10_. FIELD~ AND ~,00L, 11,, :SEC., T, a., M, OR BLOfft~F~VEY ? OR AREA 20. I 21. PLUG, BAC~ T.D., MD & TVD 6669i I~ 6448 TVD 16461 MI) 6236 VD 24, P"ODUCING INTEI~¥AL(S), OF ~HI' COMPLE~IO~ ~OP, BOTTOM, 5820~6020 Hiddle Kenat 4610 6110-6420. H~lock, 5894 26. Ti~ ELECTRIC AND OTHER LOGS RUN I~S,~ Dual Induc~ion, Sonic, Fom, ~nsi~ from Surface Location i1~. PERMIT .i18, 196~ Nov. 17, 1966] Dec. 6, 196~ T~AL D~A, ~ i ~ 22. ~ ~LTIPLE ~MPL. 23. INTERVALS ~ ~N~$ ~ DRILLED B~ ~ct. 17, 1966 ~enai.Pen. I. AlaSka [ isi ELEVATIONS (DF, S~S, aT, O', ETC/)' I 19' ELE'' CaSi~aEAD 112' 'R:.T. above M.L~L,W.. . aO~aR~-'~0LS Ci~U~ TOOLS J 6669. ~!' BURV~ MAD~ -. . ~ L Yes · '' [ 27. wis, wE~ coag~ Yes 28. : CASIN~ RECO~ (~e~rt~ll~trings set in well) · ~8~ 61 I ~ ' ' 9 5/8' 40-43.5 654~ ,~. I ~ i/~ ~ -I / 1150 sac~ ' ' ~ 390t ~ x [~ ~ ~:~ [:-DV" Stage Collar 1080 s 29, LINER RE~R~ - Dr" b, ;~'~ ~ m ~ = '~ ~ -. :i ~0. TUB~N~ RECORD ,,_ / . / ~ ~ ~ ~ ~ .,-: ./ 2 7/8 4591 .. 4587'~ .-- .......... '~.'~ g~ .... ~)~.~ ~ -~1 ~ ~- . -'~ID, SHOT. FRACTURE, CEMENT SQUEEZE ETC.' ~ ~ ~.' ~ ~-~ ~ ~P~ 'INTERVAL tMD; AMOUNT 'AND KzND Or : .................................................. ~:J ~_74, ._ . '. Dec. 7, 1966 I FI~tn~ fron H~i~[ · a ~ 'F :._ '] - S.I, F~ x~G ~ CASINO PR '~: ~ ~ CALCUL' ~ ~ OI~ B~ ~ ~' GA ' ' --~ -- ' --~-- ' _. Jeu , rac~er / ' > I ~55~c ~1~250" '-' f water - ' - j' ~31"~.. , WITN B ~ea~ed aad bused ~. ~. 35. LIST OF ATTACHMENTS ~ t:. , LP tP , aG. I hereby cert~ that the fo~go~n~ at~e~f~mation ts complete a~cor-reet as determined from ail avail~~sOp · (See Instructions on~ S~ces [or Additional Doth:on Reverse Si~e)-':- ' ' ' ' ' ; ~ :' INSTRUCTIONS ~O ~' ~2 . ~ O . :' General: ~his f6rm is design~ for submitting a ~p16~ and correct well completion repo~ and log on all types of lands~nd ~. left. s ~ ei~e~ a F~eral agency or a state agency, or both,"pu~u~g to applicable F~eral ~d/or S~t~laws and re~lations.: Any'necessary s~ial instructions cOnceding, the use of thi~f0~m and ~e n~ber of copi~ to ibc submitted, partiCUlarly-with ~gard ~ l~al, area, o~:~onal procures and practic~, either ~e shown below or 'will b~su~ or ~ ~ ~-~ ~-~ ~ ,~, ~, ana/~ ~m~ om~. ~ ~tructwns on items zz an~Z$ Rna ~c.~gw regaraJng separate reports for separate completion. ~ ~,, ~ ~ no~l~ prio~Yt~ t~e ~me t~ s~m~ry r~ord ~ ,~u~i~.~ '~pi~s. of a~l c~rren~ly available ~logs (:drille~, geologists, s~ole.~qd core ~a[~Sis, all ty~s electric, etc.), forma- uon an~ pressure ~eSts/a~d .~ec~onai surveys, sh0~be at~cne~'nere~o, to;~he extent requlr~ ~ applicable F~eral and/o~:S~te law, and re ti ns h sho_,.~ ~. .......... ~__ ~ ....... . ~ .. ~ ~ ., ~. ~ ~ o . All attac merits orffemF~eraI ~: If, offi~'forthere-aresp~ificn0 ~plicableinstructiq~s.S~te r~uireme~,~c ~l°cati°ns on F~eral o~ Indian land shoed be describ~ in accordan~ ~ith;~ F~era~uirem~M.c~ Consult. locar:State I~em ]'~: Indicate which elevatio~ isr,used as refe~c~(where not o~erwi~ ~own) for depth measuremen~ given in o~her sn~es on this go~ ann ~ ~.~ .~.o~.~. ItJ~ JJ j~ J4: I~ t~m we~ is ~ple~ ~or separa~e:~roduc~ion ~m more th~n one interval zone (~ultiple co~pJe~ion)~so sta~e i~ i~ 22] and in i~~ ~4 ~hnw th. interval, or intervals,.. . top(s), ~o[~ (s),.: .... and ~a~e~)~(~. any). ~or only..~he i~erval re~ ~ i~ ~. Bubmit~a. ~p~ate r~o~ (page)..Cbn ~." ~, ad~ua~ely, l~eGtl~,' ''' ' for each additional interval t~e separably proud, showing the addltlonal~ata pertinent to such interval~ ~., · ~ - . ' : ~ ;': ~ ~ .. ' [~em ~: "~acks Cement": .~t~c~ supplement1 r~s for t~ ~eH shoed ~how'the de~ils of ~y multipl~ s~ge ~m~ting '~d ~e lo~tibU of the ebmenting ~ol. [tzm ~: Submi~ a ~pa~t~ C~p~e~on re~ on ~ fb~m for..ea~ interval t~e separably produc~. (S~finst~ti°~or items 22 and 2~a~ve.) .. 37."Su'.'MMAR¥ OF 'POROUS zONEs: · ~; ~ t"': ,~.. . .~ . ,,, 'L; ,,,, . · ~..,,, ~- O ;'~ ~ . ' ~-- SHOW ALL IMPORTANT ZONES Or PoRoSiT~ AND CONTENTS THEI~EON; cORED INTERVALS; AND ALL DRILL-STEM TESTS, INCLUDING O~ DE~H INTERVAL.. TESTED~.~. CUSHION USED,.. TIME TOO~P~N~,D '~LOWING.. AND: SHUT-IN PRESSURES~. AND R~COVERIES~ . . ]FORMATION f'.t TOP BOTTOM 2: ~ ' DESCRIPTION, C'ONTEN~ ETC.~. ~ ~ ~" '~-- ~ T~" '" TOP 11~8/66 590-~] ~ 5~779 h DST 5820-{850, i960, ~990-6020. Packer '~ ~ a~ wig ~..~ ~ '59)5. ' .Opened*~ool at 8:04 A.H.,~a~er c~hi0~n~:~o Top _.~ surface in 5 ~nutes-~Surface be~ 1/~'~~ '~ ~ '" ~ . ~Avera~ gas. . prod, 10:00 A.H. to 1:30 P.If. 1735 HCF/day. ~verage :gas ~Qd. ~.~ . - :' 3--:hoUrs-, t~rough 3/16" Surface bean 4720~ ~F/day...~at~ =~sU~ac~ ' ~ess. 17~. PSI ~ ~ -~ ~ ~. ~. , ..... ~ . ~ ~ ~ - . ~ddle Kenai 4708 ~-: 5800 ._P!ssible Cas (Not TesCed~ . · c, Hiddle Kenai 5817 ~ 6020 ~s (Produc~ive Zone) . ~, ~ ~ · H~lock .6105 ·~° 6425 ,~.z (Productive 1o~) ~:' '> - _7_~' ~- 6006 :..~ -~ c ·: ~ ~- Core ~o. 1 59 ~ 4, Rec. 27' ~. .= m ~ ~re No 2 6261 ~ 6273 ~ ;--:ffec. 7' = ~" =' ' =: ~ '-Cdre No. 3 6371 '-: 6379 ~ /'~R~c. 8' ~' r,' ~ -'." ~- -~ ~ ~ ~ ~ O 7_i ~ L~ ~ - DH-12 Release Date 1-6-69 State of Alaska Department of Natural Resources DIVISION OF MINES AND HINERALS Sec., Petr°leum Branch T. R. 13W _ , _ : INDIVIDUAL WELL RECORD S Her[dian Permit No. , 66-4g Issued ...... 10-17-66 Operator Union Oil Co. of Calif. Lease No. : ADL.18731 or Owner ~ading Bay State- ,,. Well NO. A-2 Spud, Date ...... .10'18'66: Suspended Completed (F-GL-P) Location (Surface) 1613'FSL & 570'FEL_~__Sec. 4 _ ;Loc. (Bottom)_!98.,O'FS,L.,&,,l~80'FEL_. sec.~_~ Area Trading. Bay,,, D,rilling Ceased~ ,-, - . : : . ~ :: :. Total Depth 6669' ~ Water depth 62'NLLT Abandoned Elevation 112 R.T. ~,j,, -_ ~ -~ -:.~; ~- . __ ~; .-_ ~. ; ~: · _. __ ~_~ .; . :; ~-.-. 12-6-66 IP 555 B/D, Grav, 31° . APl Cut 0 ~; Gas 250 MCF/D, Bean 22 _ _.L ti Casing: : Size _~ .Depth, S,xC. mt,. CP -- j,psi, TF, ~340 ~_ ~; ~psi Pe rf: .5820 ' -6420 ' 4- 1/2" ]tp£. ab. intervals 13-'3/8n' 1023' 950 : ' ' 9-5/8"-40~ 6546" _ 1150 :-(shoe_) ......... (3903') 1080 (st. cO11~r) Plugs ......... . ~65.46'=6,_461' .... .(.did not drill out) GEOLOGi C FORMATI ONS PRODUCTI VE HORI ZONS Surface Lowest Tested Nam Depth i, _ i j j_.. ii . i , Con ten ts Year Jan _ ..Feb ,,,,.,._ ,i~a, r_ ._-Apr Hay WELL STATUS June July Aug Sept Oct Nov Dec - - --, ,:_'__'_-_- ' _ -~ ,, - ~"~;i; ,,''-~:-~ .i_~ i_; , Remarks: CO1/TRA~R: Caldrill, Inc. OIL COMPANY OIr CALIFOF~A COR~ R~:CORD 1/2 ~>~c Tradin8 Bay F,~,~. Unign 0il , t'I)M[~ANY OPerator -~s- T.B, State A*2 .w~ M0nopod Dritlin8 Platform, Cook Inlet, Alaska .. _LOCATION 112' RT . , ,I~rVATION D.,LL£. ' TOTAL O,L ~^V DATE CO~INO. 81ZEiARREL & ~ F~ TO REC'RY ~ALE ~ND SAND BHELL DE~RI~I~ ~ ~ __ DIP ~1 Ho~OF 11/10/~16 1 Christen- 5979~ 6006 27 .5 5979-79.5 ~en 7 5/~ OIL SA~ Diamond Very fine, fine, med-gralned salt & lZ 3/4 Core Hea.] pepper, sub-ang to sub-trial, fair 6~x4x34. ~8 sorting, friable, good porosity perm; even med brn otl stn, dull mustard yel to gold fluor, yel milky white cut fluor, It straw cut, stag sweet petrol odor. .25; 5979.5-79.75 Siltstone ~ra'y, 't~minated, abund biotite 45° ~ flakes o~ beddin~ planes. 5.25 5979.75-85 OIL Fine, medium-grained, occ coarse grained, mi~or amounts mica, salt ' pepper, subrounded, fair to good sorting, fair porosity and perm, friable, oil shows as above except straw cut. OZ~ Pr'ed~m-~oarse grained, some fine to medium, occas granule & rdd peb-i ble ~o ~" pebbles of white quartz, gray chert, black fine grained ig- neous, green vol, fair to poor sort- ing, some clay, fair pot & pe~, ] friable, oi~ sh9~. as_above 2.5 5988.5-91 OIL SA~ Fine-medium grained as In 5~ foot " unit above (lt straw cut at 5990)~ ,, . : ;: : __ - ...... ~ -- _ ~ ,,, , L. ~ ", I_ , 4 5991-95 , OIL SA~ 'Med-coar~ gralmed to granular w/ occa~ floating rdd pebbles as bef, whole inte;val is in fault or frac- E ture zome, nu~rou; slickensLded R E C I V [ ~ surfaces f~om 42° to 70°, firm to hard, calcar cmt, low pot but still DEC 2 1966 ~.d brn even o~1 stain, dull yellow fluor, dark straw cut, creamy white Ol q'~lON O~ M ~S m ~IN~ cut fluor, g°od odor as before. 3 5995-98 OIL SA~ Fine~ to medium-grained as in 5~ _~ unit above ....... ~ON 'OIL COMPANY oIr CAUFO~ CORE RECORD Bay T, B State A- 2 LOCATION .... m fVATION DRILLER APP'T ANGLE DATE COil 81ZI & TYP! ~ TO 'rOI'AL iHAL! OIL (~AY GHE:LL DE~CRII~'ION OI~ ~ O~' NO. iARRrL I~I~C'RY ~AND 5AND DIP HOLi 1 3orim g 4 5998-6002 com I:'d Kate O!L SAND . __ ..... M,,i~./~t Med to coarse graine4 pebbly to 5979 80 2 congltc, pebbles Co 2 inches, aver. 81 1 age ~", as above, matrix sub-ang 82 1 Co sub-rdd, poor sorting, fair pot- 83 1 osity, friable, even med brn oil 84 2 s~aln, dull mustard yellow fluor, 85 2 milky whi~e cu~ fluor, st~aw cu~ 86 1 except 6000-02 c~eamy cu~ fluor & 87 1 da~k st~aw cut, good sweet petrol- 88 2 _ - eum odqf, ........ ___~ _ _ _- .... _ .... 89 2 1 6002-03 90 2 QIL 91 2 -F[ne"g~alned, sal~ & peppe~, sub- 92 3 ~dd, well soreed, fair porosity & 93 3 ~ pecm, co.on c~oss lamlnae composec 94 4 of biotite flakes, o~1 shows as 95 2 above. 96 2 ~--~' ......... ' .............. ' ..... 3 6003-06 97 2 ~ OIL SA~ 98 2 Medium-grained, salt & pepper, sub. 99 2 6000 3 rdd, well sorted, good pot & pe~. 0l 4 Co.on biotite & muscovtCe· flakes, 02 4 occas bedding lamination, o~1 show~ 03 3 ...... ., . ..... as abov~ ........ . .... . _ . 04 3 05 4 06 ' Cozed 27 ' Recovered 27' No lost recovery DEC 1966 ~q~ N'fl~ m OIL COMPANY OF CALIFORI/-~ CORE RECORD Trading Bay ~,~L~ Union Oil f'_~II.I~ANY OPerator ,.~__.. T.B. State A-2 w~ Trading Bay Platform, Cook Inlet, Alaska Loc^r,ON. 112.' RT ---VArJO~ ! · · i i iiii DRILLER (~ ! APP'T ANGLE co~! 81Zl & TYPI FROM TO TOTAL IHAL! OIL Y OF ·. DATE NO. I~KRREL REC'RY ~1~.~I SAND! 8HELL DE~4~RII~TIO~i OI~ C43~! DIP HOI. H 11/13 2 Christen. 6261 6273 7' 4' 6261-65 sen Dia- OIL CONGLOMERATE mond Hem( light brn matrix, predom sd, f to 7 5/8 c-gr, mostly medium grained, s-d, 6%x4x34.';6 s/flaky carb mat, pebbles & cobbles to 5" of igneous rock and milky qtz, 20-50% sd matrix, 50-807. pbs & cob, p to v poor pot & perm, 100% it brn stn, mustard fluor, straw cut turning dk b~n, dirty milky white cut fluor, fair to good pet- rol odor, free..oil on core surface. 1- 6265-66 OIL CONGLOMI]RAT~ 11111 As above except clayey slty matrix, _ . . ~ slow brn .cu.t_ ................ 2 ~ .6266-68 _oi CON ,czem As above except very broken, cut & fluor weaker than above, at 66.5 several large bk ig' chunks with free oil on frac, last 2 feet more cq.arse (larger clasts) ..... 6268-73 No recovery · REMARKS -- Upper 2-3 feet fairly firm, remain- , der poorly consolidated. Coring ..... . time 90 min., 7.5 rain/ft. - CORED 12 REC 7 _ _ NO P. EC 5 RE(FIVED DEC g Z 1966 DIVISION OF MINE5 & MINI:RAL~ ANCHORAGE / Fo~l 7aeA ~L/~ ~M OIL. COMPANY OF CAUFOR~-h, II i I i HI Il DRILLER TOTAL APP'T ANGLE cON[ OF DAI'~ No. SIZE & I'YP~ FROM TO [RwC'lq~l/ ~,HAI.~ OIL i ({~lkY SHELL , DESCRII~TION M ~ ·AND SAND DIP MRREL HOL~ 11/14 3 Christen, 6371 6380 9' l' 6371-72 sen 0I~ SAND Diamond Lt brn--'-''~v fn-fn, angular to sub- Head ~,,.: 5,~8 rounded, diff friable, micaceous 6%x4x34' ~8 w/Chin streaks black coal, good sort, massive, fair to good p&p, 80% sin, dull canary yell fluor, clear blue white cut, fair pet odor. @. 6372...c..qa__!-._.-d. u!l_ ( frag)~, _ ,_,,,~ ~, ,,_ ~_ : : : 1' 6372-73 _O. lt SAND 45° 7%5'. Lt tan, v-fine to fine w/occas mod gr w/slight trace igneous vari- colored grains & quartzites, very micaceous, (fr coal), ang.-osharp-- to subang. Fair to good sort, dtff friable, fair p&p, 95% grain sin, dull camary yell fluor, milky blue white cut fluor, fast mod dk brn cut, good pet odor. _ ~t_ __ ~ .... ' ...... ' "'--:- : ' - - - : -- ~' - --' "' 1' 6373-74 OIL SAND ~ sca, 1007, dull canary yell fluor, mod dk brn cut, milky b~ue white w/yellow cut fluor, good pet odor, ........... , I . _1 ILl 11 '~"-~; ...... 6374-7b ou, Lt mod bm, silty to fine, angular to sub rounded, mod firm, micaceous, fair sort, massive, fair p&p, dk bra cut, fair pet odor, 100% sat, 9070 ' mod to bright canary yell fluor, milky blue white cut fluor (w/slight yellow ca..st) ...... 1' 6376'77 45 4f OIL SAND 'As aC 6373-75 except difficult friable to firm, 707° grain sin, dk brn cut,,, fair odor .. R£C[IV£D 2 Z 1966 DIVISION OF MINES & MINERAL5 ANCHORAGE COR& RECORD Trading Bay F,z,n Union-Marathon .. d_._~.iMPANY T.B. State . L,_~_.~ A-2 Trading Bay Platform, Upper COok Inlet LOCAV,ON 112' RT. FOAM ~7oe& ~/1~ IM -,,,-'~-, ,.-.~ ON OIL COMPANY OF CAUFOK A CORE RECORD Trading Bay ~ ._._.. A- 2 ,, w~ (Core P3 cost'd) LOCATION, " : " 'APP'T DRILLER T(FTAL OIL ~AY I ANGLE DATE co~l 81ZE & I'YI~ FRO~ TO ~AL[ D~RI~I~ ~ ~ DIP NO. REC'~ ~NO SAND ~HELL OF ~RREL HO~ - _ , ,,,,., 11/14 3 (COhO'd) , 1' 6377-78 , LC Co med bm, silty to fine~ angu- la:~ subrounded~ dtff, friable, : caceous w/thin streaks black coal, fat; to good so:C, massive, fair poor p&p, very dk brn cut, fair good pet. odor, 80~ sat, dull b:n fluor, milky bluish yell cut ~ ' 6378- 79 OIL lilt As at 6377-78, firm, minor scat:erec pebbles, ~00"~ lC ~o wed b:~ stn, me( canary yell ~o 1: dul[_~:p flug~ 1 ' 6379-80 Med bt.n, silty to fn sd matrix, angular to sub angular. Qua:czice cobbles/boulders to 5" cobbles pebbles well rounded; fairly ftiabl, , fair amc mica, tg g:ai~s) qua;tziCe minor Tuffaceous conc:etions~ poor sort, massive, poor-fair p&p, dk brn cut, fair to good pet [~00Z (matrix) dull orange b:n fluor b:iRht canary yell cut fluor. . .... ' - u ._~, _ _. . ~, , . ~ ~ _ ~..~. :' T · _ r-: : _ · " ' - Coting time: 6 mtn--upper 4' 13 min--lowe~ 5' C~D 9' ~C 9 ' Note: Barrel was pulled because of plugging. RECEIVED B Eg 2 g 196 6 · PlVISION OF MINES & MINE~ ~CHO~GE , ':"~" ALACAL DIRECTIONAL DRILLING CORP. aD. ~. ,,' ~&~'"., 888 No. Main Street · Santa Ana, California 92701 ~.Hlll' NO.. -~/~ '5~ ' D~C~R 1966 COMPANY, ~ION-MARATHON WELL STATE i~A-2 .LOCATION, TRADING BAY COUNTY KENAI BOROUGH , STATE_ ALASKA 141rAIUI~ED COURSE; Ol;VIATION !i VERTICAL DEPTH DEPTH 7NGTH [ ANGLE__i,''-r:-'=:i COURSE TOTAL os:ti6al , ,._o_q COURSE DIRECTION DEVIATION DEVIATION _._o_._.0_o .... ___0_.?_0_0_ __~e__~_ .t'_~.~?_ COURSE ...... -~ ~ U-~i-~ ..... ;[ ....... DEPARTURE LATITUDE TOTAL NORTH i SOUTH 385 i 0 15il 385 00/~ 0 ;+1 S 55 W l ~ I i ' I , 0i2/4 /429 , :~ ] ~ J ~ , ~ , .... ~ ............ j .... -~--i- !,- ' "= ................. F=-I ...... ]~-- ~ ............ i--1 .............. . .... ~ ...... ~k--'q ........... - ........................ ,--~ ......... I , ~ 30~ 675 2~,L 9~j,~ 75 ~.~. ,, ,~ ~ ~ ~,95[ ~ , i il0 301 _ 705.t69~. 5!.65:N' 70 IW I _._ L J i! 6 88 953 il .18130ji , ~ 9&0~95 31!10IN1 61 ~;~ i ~ i ', '. . ,~ 36;26~ 't 10&6 i, i 18] 301; i 1029 ~ 29 51 N 60 w~ i " ~ i~, , j ~ 51i 02 i ~1~8 30~ ~ ~097 ~2~22 85tN, 61 W . t . : 62, ~0~ . 20 30~ I , 1165 92. 11 21,N 67 W , ' '~ , 721 85 ~ ~ ~ 20 30 ~ 1196 831~' ZZ. 56 N 7[ ~ wi ~ ~ 761 6Z~[ ' , , " '~ .............. ~' ~ ~ ~ ........ i .......... ' ~ I Jl I IJ tl I ,~ ~ 'L J I i DEPARTURE 15& -- TYPE OF SURVEY: .. CALCULATED BY CHECKED BY. co~,^~v. UNION-MAI~^TFION ALACAL DIRECTIONAL DRILLING CORP. 888 No. Main Street · Santa Ana, ,California 92701 .__ADDRESS ,, COUNTY KENAI BOROUGH .o. 2//,, ' ~ 1966 W£LL STATE #A-2 _LOCATION TRADING BAY .,,A"UR.OICOUR.., D.'V,ATm. il VERTICAL DEPTH cou.s[ il DIRECTION COUJ~SE ; OF [i ....... ~ A~U'D--~ .....i'J .... bEPARTURE i LATITUDE OII~TH jj LENO?H ANGLe i! COURSE -i TOTAL DEVIATION DEVIATION ......... O0 STATE_ ALASKA 161k 1770 192~ 2082 1559 1706 1850 TOTAL DEPARTURE 2239 2332 2k88 26A/+ .2801 2895 2988 _ 308& 3178 3271 3362 3Z,.56 3~71 3502 il lz"/.,.5 ii 12t 2000 2150 && 1691 75 239 95~, 25 7~ : ~ ! ,, 176: 71, 25&1 ~8~ 39~ 72~ N] 7~ ~,, , I ~ , I~ I, 198 79" ' 2785 92 20 35IN 7& ,~ :': ~ : ; , 2],, ~0~ ' t 2876J72 20 13 N 7& ~ ~ ~ ~ :+ ~ ~ ~ 220 05 , t j 2970~&& 20 ~ N 7& ]'.~ ~ ~ 225 3152 83: 20~ 52 N 7& ~.~: ' ~ ~' ' ' ~ i 2 7 1 32&0J 8!1 231 1~ Nj 73 ~ ~ : " ~ ~ Il 2&3J 92~ ~ " ! ~.J 76~62 "~ ~ I J [ ~ I~ 33&& 9~ &l 39 N 72 W ' ,j 2 81 ' 25? TYPE OF' SURVEY' CALCULATED BY ,,, CHECKED BY. ALACAL DIRECTIONAL DRILLING CORP. 888 No. Main Street · Santa Ana, California 9270! JOE N~, ' COMPANY UN!0N-MARA~ION ....... ADDRESS__ SHEET NO. 3/ZI, ' ' . DEC]~,~BE~ 1966 WELL ~AT~, # A-2 LOCATION ~'-~DING BAT __ .COUNTY_ KENAI BOROUGH STATE ALASK^ "t' VERTICAL DEPTH DEVIATION ~< TOTAL /,278 /+/+32 ~525 ;+592 ;+609 /+639 _ ~73~ &878 lj 1 /.,.5; 5016 5060 13 ~5i 12! &5 COURSE DIRECTION lj COURSE !i TOTAL OF' lJ LATIT.U DE __.jJ DEPARTURE LATITUDE .' DEPARTUR~=' DEVIATION DEVIATION SOUTH EAST ;I WEST NORTH SOUTH 'i .... N 83 ~_~,",' ~ ~ j . j j ~ 862 67 - ~i~ I. [ ] ] ] 269 50 .... 28 -LS'i ~,. n~16 33~ 17~ 38J N 70 WJ ~ ~ ; J J~ ? 310 15 J j J ~ 1075 32 ~32~59jJn 97 NJ 7~ IW ~ : ~ : : ~ ,~ 311 51t tl/ j 1080 10 i A~61.32,i 8 j 65 N 75 ~[ , , ~,1 ., ~ .,, :' 313 [ h552 6~ 26 19 NI 7~ i~: ~ ~' ' :' i : 320~ 97'. '~ ~ :j 1113 63 , t-~p ............ , j ~_~ ............ I,. ~ ............... t--'~. ................... ~691 89~ 36 66 72 ~: ~ :~ : ~:'~~' :: 332 29'~ !j ll&8 50 ......... ...... ~ 4[ ~ ,, ~5 TYPE OF SURVEY: __ CALCULATED BY CHECKED BY ¢OMP~m~ UMI 0N-~IAR A~ION WELL STATE #.A-2 ..... ALACAL DIRECTIONAL DRILLI.NG CORP. 888 No. Main Street · Santa Ana, California 92701 __ADDRESS do~ N6.,' , ' s,,. ,o. z~/g ' · DECFJ~BER 1966 LOCATioN_TRADING B AY · COUNTY KENAI BOROUGH STATEi ALAS¥~A I,tEAmURED COUR$1rl DEVIATION !I VERTICAL DEPTH .DIPTN LENG?.it ANGLE i! COURSE TOTAL 5 366 it .ii 5 736 .t 892 016 12 3 198 316 371 15 56 COURSE DIRECTION ii COURSE OF , ..... ---~1'~' :T-i~"~E ....... '] DEPARTURE DEVIATION DEVIATION NORTH :! SOUTH /I CAST ; WEST ~ 5376 5527 5680 5~01 5906 sg~o 6037 ,; 16097 63~9 .... -7[ 72'9 07 1 31t 5 ~6 i~ 6236 05 ? 61 TOTAL LATITUDE DEPARTURE NORTH i SOUTH EAST 359 98 i! .392 L t. TYPE OF SURVEY:, · CALCULATED BY CHECKED BY 6669' M.D. 6 447. 79' V.D. N. 455. 57 ' W. 1463.85' UNION OIL COMPANY OF CALIF. TRADING BAY- STATE~'2 TRADING BAY, ALASKA ALACAL CI"o,.~UR.~ SCALE: I"= 200' -"",,o · ISURF. LOC.~'28 / ~orm STA," '"OF ALASKA SUBmT IN TRIr 'ATm. (Other instructioL n re- OIL AND GAS CONSERVATION COMMITTEE verse side) , SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Effective: July 1, 1964 5. LEASE DESIGNATION AND EERIAL NO, ADL 18731 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. 7. UNIT AGREEMENT NAME Union Oil Company of California 3. ADDRESS OF OPERATOR 507 W. Northern Lishts~Blvd., Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surfsce 1613' N., 570' W of SE corner Section 4, T 9N R 13 W., SM ELEVATIONS (Show whether DF, RT, 112' g. T. Above M.L.L.W. 14. PERMIT NO. 66-49 TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) 16. 8. FARM OR LEASE NAME Trading Bay State 9. W~LL NO. A-2 10. FIELD AND.POOL~ OR WILDCAT Trading Bay, Middle Kenai, SURVEY OR AREA Sec. 4 T9N, R13W, SM 12. BORO~IGH [18. STATE · eaai Pen. I Alask~ Check Appropriate Box To Indicate Nature si Notice, Report, or Other Data NOTICE OF I~TENTZO~, TO: RUR~EeUENT ~E~'O~ O~: PULL OR ALTER CASING WATER SHUT-OFF [-~ REPAIRING WELL MULTIPLE COMPLETE FRACTURE TREATMENT [--I ALTERING CASING ABANDONs SHOOTING OR ACIDIZING ABANDONMENTs CHANGE PLANS (Other) Multiple Completion NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is dlrectionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * The~iddle Kenai Zone was perforated with 4 - 1/2" Jet holes per foot from 5820 - 5850, 5900 - 5960 and 5990 - 6020. The Hemlock Zone was perforated with 4 - 1/2" Jet holes per foot from6110 - 6140, 6150 - 6285, and 6300 - 6420. Set single packer at 6039 with tail to 6108. The dual packer was set at 4587 with tubing tail to 4594. Plugged back depth 6461ND, 6236 VD Top of perforated l~Lddle Kenai Zone 5820HD ~610 VD, 387' N., 1352' W of surface location. Bettom 60201~, 5806 VD, 403' N., 1391' W. of surface location. Top of Hemlock 6110 ND, 5894 VD; 411' N., 1406 W. of surface location. Bottom of He~lock 6420' ND, 6200' VD; 435' N., 1446' W. of surface location. 18. I hereby eert,ffy that th.e forego~ is t~e and correct -~. D.. MaMahan TITLE Drilling Superintendent ~ATn Dec. 12, 1966 (This space f°r F~F~Z~ff_~ APPROVED BY coNDITIONS O~ ~'APPkOVAL, IF ANY: TITLE *See In,tructlons on Reverse Side Form~P--3 STA'; '~DF ALASKA SUBMIT IN TRIP' h~TE* (Other instruetiom ~ re- OIL AND GAS CONSERVATION COMMITTEE verse Side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Effective: July 1, 1964 LEASE DESIONATION AND sERIAL NO. .U)L 18731 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. ?. UNIT AGREEMENT NAME 2. NAME OF OPERATOR Union 0t1 Company of Caltf&rnta 8, ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surf. ce 1613' N., 570' W. of S. g. corner Section 4, T 9N I 13I~, SH 8. FARM OR LEASE NAME Trading, Bay State 9. W~L NO. 10--FIELD AND POOL, OR _WILD. CAT Trading Bay-Nld~le Kenat= SURV,, OR AREA Sec, 4, T 9~, 14. PERMIT NO. I 15. ELEVATIONS (Show whether DF, R?, OB, et~) 12. BOROUGH 18. STATE 66.--49 [ 112' R. T. above MLLI~ Kenat Pen. AlaS~ 16. Ch~ Appropriate BOx To Indicate Nature o[ Notice, Repo~, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT ] ] MULTIPLE COMPLETE SHOOT OR ACIDIZE U ABANDON$ REPAIR WELL CHANGE PLANS (Other) SUaSESV~N~ REPOa~ OF: WATER SHUT-OFF ~ REPAIRING WELL ~ FRACTURE TREATMENT [--I ALTERING CASING I--J 8HOOTING OR ACIDIZINO [ ] ABANDONMENT* I J (Other) , i ~ ~ (NOTE: Report results of multiple completion on Well Completion or Recompletion RePort and Log form,) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * I.t is proposed to perforate the Middle Kenat Zone from 5820 - 6020 at intervals and ~he Hemlock Zone from 6110 - 6420 at intervals. Set bottom Packer at 6050 and dual packer at 4600 and complete as a dual completion. Start work November 27, 1966. TD 6669 MD, 6448 TVD: 456' N. and 1463' from surface location plugged depth6461 MD, 6236 VD 18. I hereby certify that the foregqin~ is tr~ and correct _ H, D. NcNahan TITLE Drilling Superintendent ~TE December 9' 1966 (This space for Federa~ or/j~f om~p use) CONDITIONS 0]~ A'PP'~tOYAL, IF ANY: TITLE *See I.,~ruetions on ReveRe Side Operator: Well: UNION OIL COMPANY OF CALIFORNIA Trading Bay State # A-2 Completion Date:L_peC, 6~ 1966 Release Date: .... .Jan, 6. 1969 The Files contain the following material: Office File 1. Permit to drill and location plat ........... 2. Reports of operations and sundry notices ....... 3. Well history ...................... 4. Completion report ................... 5. Directional survey 6. Electrical log, Induction ..... , and sepia 7. Lithology or mud log and sepia ............ 8. Other log Core Descriptions e 10. I1. 12. 13. 14. 15. Release File Remarks: Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 LAND I'IF F {E:E /~ LE^s~ .,,.~. ADL 18731 LE^s~ o. ''N,. ~ Trading 8ay State LESSEE'S MONTHLY REPORT OF OPERATIONS State ____A__l___a__s__k__a__ ........................... Borough ...... _K._e__.~._.a_i_ ........................... Field Trading Bay Tl~e followir~ is a correct report of operatior~s and prod~etior, (ir~el~dir~ drillir~ and prod~eir~ wells) for the month of ___:--No~emhez ................... ,19__6~ ............................................................................. Compar~y _U__n_i_o_p.__o_i!___.C__o__mp_.a_ny____o_~___C_.a_.l._/,.f_o. rn i a .4~er~t's address _5_02__~_,__~_ox_tke_rn__hight_$__.~lv_d ........... Si~ned ' ~_'__ . ~). ~? d. ~'L{t (~.;~"'~'.- / ........... . _A..n__~__h__°_?__g_ %__AA_a_ ~ _k__a' ....................................... : ................................................................... PI, one ____2_7_7__-__1__4__0__1_ ................................................................ ./l ~ e r~ t ' s title __p_r_ikl_.i__n_g___S__ur__e_r_i__n__t_.e_.n__d_.e..n_.t. ...... WELL D~Yz. CU. FT. O~ GAS G~ONS O~ BARRELS O~ REMARKS SEC. AND VrWP. RANGE l~O. Pao~o~v (~' tho~) RECOVERED none, so state) ~te and r~ult of t~t for ~ OF ~ BARRE~ OF O~ GRAVY ~ASO~E WATER (~ (If ~, d~th; if ehu~ d~n, c~t of ~) Ran Schl~berg,~r surveys. Ran 9 5/8" 40~ and 43.S~ casi~g to 6S, 6. Comented through shoe with llS0 sacks c~ment and three stage collar at 3903 with 10~ 0 sacks cement. Dr~ll out cement to 6461 Jet p~ rforate with 4-1/2'" holes per foot from 58; 0-6420 at intervals. Now preparing ~o compl~ te as a dual completion. . NoTE.--There were ................ 110 ........................... runs or sales of oil; ............... 1%0 ............................ M cu. ft. of gas sold; ' runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must directed.be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month~hr~es~~. -~ ~'~ op,, erv ~ 0ie bc.C '~ ,,., 1966 .OiVIdlON MI NJ:'5 & Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 LAND r3F' F IC£ L~A~E.UMS~ ADL 18731 ~' ~ ="'~ '~ Trading Bay State LESSEE'S MONTHLY REPORT OF OPERATIONS State .... _A__!_a_~_k___a_~ .......................... Boro ugh ..... K_e___n_.a._i ............................. Field ___T:cading Tl~e followir&~ is a correct report of operations and prod~ctior& (incl~din~ drillir~ and prod~ein~ wells) for tl~e month of ..... _Q_c__t__o__b_'_e__r__ ....................... /9_6_~ ............................................................................... ,4~er&t's address ___5_9_!___w_:___S_o_r__t_h_e_rn__L:_igh_t__s__~_!_v__d. ........... Compa,~y ,__~n_~_o_n__,C)J,J,___C_9~!0.f___Ca J. Lf.oxn i a £hone ........... _2_.7__7__-__1_J_0__1_ ........................................................ .;l ger~t' s title ____D__r_kkki__n_g__~__up_crin.t_¢nd_¢n_t ...... SEC. AND ' BARREL8 OF OIL GRAYI~Y OASOLINE WATER (If (If dr/lib., d~pth: If shu~ down, oa~; ~ O~ ~ TWP. RANOE WE~ D~s. CU. FT. O~ GAS GAINS O~ BARR~ O~ RE~ARKS NO. Pao~o=~ (~'thou~) da~ ~d r~ult of t~t for g~o~ RECOVERED none, so 8~te) o~t of ~) ...... 4 9N 15~ A-2 ' Spudc.ed at 5'00 am, Oct,,ber 18, 1966. 15-5/~8'' cemente~ in 17-./2~ hol~ at 1025~ w~th 950 sacks ~f cemen' . Drilled 12-1/4~ - d~rec:tional to ~659~. mn Schlumberger surv,~ys. Now preparing to drill ahead. . . ' RECFIV[ 81VISION OF MINES & MINE~ ANCHO~GE NOTE--There were ................ ..ILO .......................... runs or sales of oil; ............. TkO .............................. M cu. ft. of gas sold; ............................... '. ............................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the Otb of the succeeding month, unless otherwise directed. I- C)RM 5A-I 100M 9/65 MEMORANDUM TO: F J~me~ A. ~illie~m State of Alaska D1T~S~N OF M~N~S A~D FROM: Tom llarsbal I DATE SUBJECT: October lg, 1966 Applicati~n £or Permi~ Drill o T~adiu~ Bay $~ate Union Oil Company of California Enclosed £u one approved copy of C~ above applica~ion for permit to drill along ~ith a check in ~he ~mount of $50.00 for filing fee. Jr. Form P 1 ....... SUB .MIT IN TRI.~ JATE* - : -,...-~ '~ ' - - ~ ..reAerse side) , · - · ~ OIL AND: GA~'"~ON~E'~VATioN CO~I~ION.' ' :; '' ' ' ' '' ' 5. LEASE DEBIGNA,ION *"D SE,lA, NO. .... ] 'ADL 1'873~ OIL ~ WELLS ' a----E- ' ' SZ~__ ~ Z~N-U T ~ ] 8. FARM OR "LE~SE; NAMe" WELL . ~ .... u'f~. ~ ~. . . ~ . ~ . -. ~ u ~ Union Oil Company of California '" ~: ~ - 2805 Denali Street, AnCho~a~e~.'~aska?-99503~'-. :~' 4. ~oe~o~ ~.w~ (~ep~.leeat~ .~ea, r~'~4,1D~9~4~nce ~'-anyS~te ~uirements; ) ': ~ - --~ ' Trading' Bay Hemlock ~t,,rf,,,Trading Bay Monop~ b'/U'W, 1613'N of SE corner S~c 4 ~ ' ~ / 11. B~C.,.T., B., M,~ OR BLK. T' 9N, R13W,;~SM~'-''' .... ~'~-' "~ .... ~ ..... ' ' ' ' ' At proposed prod. zone ~ ~ec. 4 1980'N, 1980'W of SE corner, Sec. 4, T 9N, R 13W Approximately 27 air miles from Kenai Alaska ' 5ena~ Peninsul~ Alaska Sec. 4, T9N, R1.3W, SM 15. DISTANCB FROM PROPOSED* LOCATION TO NEAR"ST 3667' S, Surface PRoPERT. on LEASE LINE. ,T. 6~n' ~r. Drilling Unit (Also to nearest drlg. unit line; ff ~ny ~. DISTANCE FROM PROPOSED LOCATION* OB APP~ rOB, ON THIS I.~,ASE, "Trading Bay ~I-A 16. NO. OF ACRES IN LEASE 3840 19. PROPOSED DEPTH 6000' ,. No. o, AC--S ASSIG,ED TO THIS 20. ROTARY 'OR CABLE TOOLS Rotary 21. E~.-VA~IONS (Show whether DF, RT, GR, etc.) 22: APPROX. DATE WORK WILL 8TART* RT approximately 9S' above MLLW October 20, 1966 23. PROPOSED CASING AND CEMENTING PROGRAM · 5. 6. 7. 8. 805 sx. 500 ," hole to 18 5 Cement 13 3/8" 61~ J-55 casing at 1000' Install 12" 3000~ shaffer double hydraulic gate and GIC Hydril Testcasingand B.O.P.E. to 1500 P.S.I. Drill 9 7/8" directional hole to 6000' MD Run wire line logging services as required Cement 7" 26~ 1-55 casing at 6000' Perforate and test for production No affected parties, deviated development well as per development plan. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If propo~s to dri~-~or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. ' Give blowout preventer prog~m~/if~ny. I / ' 24. I hereb~e~tl~'-- !/ F ~_n_g is True and c~rect. SI~D ~' ~' ~_'T[.__.~ TiTLEDistrict Exploration Geo1ogis~ATE October 13, 1966 (This space for Federal or State office use) APPROVAL DATE 1TIOMAS. R. MARSHALL, TiTL~Xec~tive Secretary Alaska Oil & Gas ~:mservation Commltte~ DATE RE *See Instructions On Reverse Side tJI T 13 1966 DI¥1~ION OF MINES & ANCHORAGE ~~/ TEXACO T.B. ~2 · ATLANTIC RICH FI ELD MIDDLE RIVER#1 UNION TEXACO 2 0 TRADING BAY fi= I I ° 32 ,.33 ~o 33134. , , 34 ~,.5 0 \ \ ~ I PLATFORM .__~8~~__ 4.53 91 JO UNION-MARATHON T 9 N -R 13 W ADL- 18731 01~ .... t7 i6 uNION OIL COMPANY OF CALIFORNIA ..... ALASK. A DISTRICT R E C E IV E F) LOCATION MAP ~ 13 1966 N I I -o,v,s,o,,, o,: ,,,,,,,,.s & ,,,,,,,,,,.,,,,.~ TRADING BAY STATE A-2 ANQ,.IORAGE .OAT£ .OCT 1.5, ~ ScaleI" = 2:000' ,,