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Home My WebLink About173-001CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Ryan Rupert To:McLellan, Bryan J (OGC) Cc:Juanita Lovett; Dan Marlowe Subject:RE: [EXTERNAL] TBU K-17 (PTD 173-001) RWO sundry Date:Monday, June 24, 2024 11:59:05 AM Understood. Thank you for the clarification. We did get on the well this weekend and attempt an injectivity test for pre-rig diagnostics. We were unable to sustain injectivity, suggesting that we are not in communication with the Perfs. Given this Hilcorp has elected to cancel this project. An official sundry withdraw request will be coming your way shortly. Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 24, 2024 10:39 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] TBU K-17 (PTD 173-001) RWO sundry Ryan, I’ve researched 3 of the wells you mention where the lower packer was not tested and concluded that this test procedure was either not explicitly agreed by AOGCC or the casing damage is located relatively close to the perfs, possibly within the same pool as the perfs. See my comments in red below. In the case of TBU K-17, the casing damage Hilcorp plans to isolate is in a different pool, ~3000’ above the perf interval. Hilcorp needs to test the bottom packer to verify that the pools are isolated from one another. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Thursday, June 20, 2024 4:28 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: RE: [EXTERNAL] TBU K-17 (PTD 173-001) RWO sundry Bryan- Per our conversation, please see below and attached for McCarthur River Field wells that have recent scab liners, none of which had the bottom packers tested. One well was even approved for production without remediation once a casing leak was discovered. G-03RD2 producer PTD# 183-010 Scab ran in 2013 Only upper packer and scab pipe tested G-02RD Producer PTD#182-067 Scab ran in 2013 Only upper packer and scab pipe tested D-17RD Producer PTD# 181-023 Scab ran in 2014 Only top packer tested casing patch set very close to top perfs, presumably in same pool, which would mean the hole doesn’t need to be isolated from the perfs from regulatory standpoint. Proximity to perfs noted by AOGCC approver. -bjm Couldn’t get regular packer down on bottom, so ran a smaller OD swell packer on bottom G-14ARD Water Injector PTD#191-099 Scab run in 2015 Only upper packer and scab pipe tested This test procedure was not explicitly approved. Several changes from original sundry and no mention of test CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. procedure. It’s possible that upper packer was set below top of the same pool as the perf holes.-bjm K-13RD2 Producer PTD#201-046 Casing leak discovered in 2016, Conversation with Guy Schwartz, and agreed to just accept shallow leaks to GGS. Not remediated, just ran ESP Oil production took a step change down, so scab run in 2017 Only upper packer and most of scab pipe tested (lower packer, nor seal stem tested) 8/2/16 This was not explicitly approved or explained on Sundry. Handwritten comment on sundry said to “test casing to 1500 psi” after running scab liner. The report on 10/4/17 says a 4-1/2” plug was set at 12315’ and tested 9-5/8” x 7” liner top, 7” pkr and 4-1/2” liner to 1500 psi. This plug was set 5’ above top of seal stem. It’s not clear why the test plug was not set below the seal stem since it was operationally no more difficult to set it above or below. -bjm Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, June 19, 2024 9:08 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] TBU K-17 (PTD 173-001) RWO sundry It seems like if you don’t test the lower 7” x 9-5/8” packer, there’s no point in testing any of it? I could be missing something here. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: 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: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Tuesday, June 18, 2024 3:00 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] TBU K-17 (PTD 173-001) RWO sundry 10,677’ MD / 8687’ TVD = Top Middle Kenai G Oil Pool (per page 4) If ran, the scab will have a profile in the 7” below the bottom packer with a plug set (standing valve or B&R etc…). This will test/confirm all of the 7” scab piping, 7” x 9-5/8” upper packer, and 9-5/8” casing above top scab. Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 17, 2024 11:05 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: [EXTERNAL] TBU K-17 (PTD 173-001) RWO sundry Ryan, A couple questions about this RWO plan 1. What are you testing against in the pressure test in step 17? Is there a plug below? 2. Where is the top of the Middle Kenai G Oil pool? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Anne Prysunka at 2:46 pm, Nov 30, 2022 1. Operations Susp Well Ins{❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Install Whipstocl❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Mod Artificial Lit] Perforate New Pool ❑ Repair Well ❑ Coiled Tubing Ops ❑ Other: No -Flow Test ❑� 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska, LLC Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 173-001 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20248-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 Trading Bay Unit K-17 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): N/A McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 12,120 feet Plugs measured 11,800 feet true vertical 9,787 feet Junk measured 11,676 feet Effective Depth measured 11,800 feet Packer measured N/A feet true vertical 9,537 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 382' 24" 382' 382' Surface 2,183' 13-3/8" 2,183' 2,038' 3,090psi 1,540psi Intermediate Production 12,096' 9-5/8" 12,096' 9,767' 6,820psi 4,230psi Liner Perforation depth Measured depth 10,828 - 11,774 feet True Vertical depth 8,793 - 9,517 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 1,514 (MD) 1,478 (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf I Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 10 10 134 0 Subsequent to operation: 0 10 10 134 10 13b. Pools active after work: Hemlock Oil & Middle Kenai G Oil Pools 14. Attachments (required per 20 AAC 25,070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL LJ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 321-577 Authorized Name and Dan Marlowe „'mri"&°°�"Dan °°°"a oN: ��=oaa mama o2an, Digital Signature with Date: (1267) oar 20n.11.3°6ezal649W Contact Name: Ryan Rupert Contact Email: rvan.rupertQ7 hilcorp. com Authorized Title: Operations Manager Contact Phone: 907 777-8503 Sr Pet Eng: ISr Pet Geo: I I Sr Res Eng: Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF formal to aogcc.permitting@alaska.gov King Salmon Platform Well 1 3-0 SCHEMATIC API-17 PTD: 0-733-1 API:50-733-20248-00-00 """ j, tl "`''"'' Completion: Future KR=100'AWL r ::.r I 9 c in9 den9e ' 7,ins-7 eas Can aid SM Cas.Vdawge 9AN, Ile Cement Sz'd YM4 PonilM si q danege@ 110740 IO Son RNIO Ii<i5 (11RM) G lb IIB-1",4 ti ?II II ►�4 �-4 ' I I i ' 141 BB-6 1wk., PBTD=11,800' TO=12,120' Max HOLE ANGLE-44'. @ 39W CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24" 110 X52 Welded 23.124 Surface 382' 13-3/8" 61 K-55 BTC 12.415 Surface 2,183' 40.0 RS-95 BTC 8.835 rfa Suce 7,031' 9 5/8" 43.5 RS-95 BTC 8.755 7,031' 12,096' TUBING DETAIL: 4-1/2" 1 12.6 L-80 IBT-MOD 3.958 Surf 1,514' 11VIY141WA-1:1011 Depth Depth No. (MD) (TVD) ID OD Item 1 1,514' 1,478' Kill String(11/09/21) 2 11,800' 9,537' CIBP PERFORATION DATA Zone (Top MD) Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date Comment G-1 10,828' 10,846' 8,793' 8,806' 13 5 06/26/2014 Open G-2 10,878' 10,907' 8,830' 8,852' 22 5 06/26/2014 Open G-2 10,922' 10,946' 8,863' 8,881' 18 5 06/26/2014 Open G-3 10,990, 11,007' 8,913' 8,926' 13 5 06/26/2014 Open GA 11,040' 11,086' 8,950' 8,984' 1 34 1 5 06/26/2014 Open GA 11,127' 11,139' 9,015' 9,024' 9 5 06/26/2014 Open G-5 11,183' 11,249' 9,057' 9,107' S0 5 06/26/2014 Open G-6 11,318, 11,350' 9,160' 9,185' 25 5 06/26/2014 Open HK-1 11,419' 11,457' 9,238' 9,268' 30' 5 06/26/2014 Open HK-1 11,420' 11,460' 9,239' 9,270' 40' Open HK-2 11,482' 11,539' 9,288' 9,332' 57' 5 06/26/2014 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' Open HK-2 11,551, 11,584' 9,342' 9,374' 33' 5 06/26/2014 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' Open HK-3 11,592' 11,655' 9,374' 9,423' 63' Open HK-3 11,595' 11,646' 9,376' 9,416' 51' 5 06/26/2014 Open HK-4 11,655' 11,774' 9,423' 9,517' 119' Open HK-5 11,856' 11,876' 9,581' 9,597' 20' Squeezed HK-6 11,920' 11,975' 9,631' 9,674' 55' Isolated Fish: 11,676' - Partial Bridge Plug 11,688' - Obstruction ESP remaining in well above CIBP Updated by DMA 12-09-21 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-17 N/A 50-733-20248-00 1 173-001 11/24/22 11/24/22 Daily Operations: 11/24/22-Thursday No flow test passed on 11/24/22 (non -witnessed). 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From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Juanita Lovett; Josh Allely - (C); Dan Marlowe Subject:RE: K-17(PTD#173-001) No Flow test: 11/24/22 Date:Monday, November 28, 2022 2:27:00 PM Ryan, Please submit this NFT activity and data in a 10-404 that references the Sundry 321-577. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, November 28, 2022 9:15 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Josh Allely - (C) <Josh.Allely@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: K-17(PTD#173-001) No Flow test: 11/24/22 Bryan- Please see attached for the results of Hilcorp’s in-house no flow test performed on K-17(PTD#173- 001). The test was a pass, and was performed on 11/24/22 in accordance with Sundry #321-577. I believe there is no further actions necessary with regards to this sundry. Please let us know if any further action is required. Thank you, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) 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, pleaseimmediately 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. From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:TBU K-17 (PTD 173-001) wellfile Date:Monday, November 28, 2022 2:28:39 PM Attachments:RE K-17(PTD#173-001) No Flow test 112422.msg Please add the attached email to the wellfile, in association with sundry 321-577. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 2SHUDWLRQV $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 3XOO7XELQJ 2SHUDWLRQVVKXWGRZQ 3HUIRUPHG 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH $OWHU&DVLQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HSDLU:HOO 5HHQWHU6XVS:HOO 2WKHU,QVWDOO.LOO6WULQJ 'HYHORSPHQW ([SORUDWRU\ 6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU:HOO1DPHDQG1XPEHU /RJV/LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$&)LHOG3RROV 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ 7RWDO'HSWK PHDVXUHG IHHW IHHW WUXHYHUWLFDO IHHW IHHW (IIHFWLYH'HSWK PHDVXUHG IHHW 1$IHHW WUXHYHUWLFDO IHHW 1$IHHW 3HUIRUDWLRQGHSWK 0HDVXUHGGHSWK 6HH6FKHPDWLF IHHW 7UXH9HUWLFDOGHSWK 6HH6FKHPDWLF IHHW 7XELQJVL]HJUDGHPHDVXUHGDQGWUXHYHUWLFDOGHSWK / 0' 79' 3DFNHUVDQG6669W\SHPHDVXUHGDQGWUXHYHUWLFDOGHSWK1$ 1$ 1$ 1$ 6WLPXODWLRQRUFHPHQWVTXHH]HVXPPDU\ ,QWHUYDOVWUHDWHGPHDVXUHG 7UHDWPHQWGHVFULSWLRQVLQFOXGLQJYROXPHVXVHGDQGILQDOSUHVVXUH1$ 3ULRUWRZHOORSHUDWLRQ 6XEVHTXHQWWRRSHUDWLRQ :HOO&ODVVDIWHUZRUN 'DLO\5HSRUWRI:HOO2SHUDWLRQV ([SORUDWRU\ 'HYHORSPHQW 6HUYLFH 6WUDWLJUDSKLF &RSLHVRI/RJVDQG6XUYH\V5XQ :HOO6WDWXVDIWHUZRUN 2LO *DV :'63/ (OHFWURQLF)UDFWXUH6WLPXODWLRQ'DWD*6725 *,1-6863 63/8* 6XQGU\1XPEHURU1$LI&2([HPSW &RQWDFW1DPH &RQWDFW(PDLO $XWKRUL]HG7LWOH&RQWDFW3KRQH SVL SVL SVL %XUVW &ROODSVH SVL PHDVXUHG3OXJV -XQN PHDVXUHG 1$ /HQJWK 6L]H &RQGXFWRU 6XUIDFH ,QWHUPHGLDWH 3URGXFWLRQ /LQHU &DVLQJ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 5(32572)681'5<:(//23(5$7,216 1$ 3HUPLWWR'ULOO1XPEHU2SHUDWRU1DPH :HOO&ODVV%HIRUH:RUN $'/ 0F$UWKXU5LYHU)LOHG+HPORFN2LO 0LGGOH.HQDL*2LO3RROV +LOFRUS$ODVND//& &HQWHUSRLQW'U6XLWH $QFKRUDJH$. $GGUHVV 7UDGLQJ%D\8QLW. PHDVXUHG WUXHYHUWLFDO 3DFNHU 5HSUHVHQWDWLYH'DLO\$YHUDJH3URGXFWLRQRU,QMHFWLRQ'DWD &DVLQJ3UHVVXUH 7XELQJ3UHVVXUH $WWDFKPHQWVUHTXLUHGSHU$$& *DV0FI 0' 6WUXFWXUDO 79' 6U3HW(QJ6U3HW*HR6U5HV(QJ $XWKRUL]HG1DPHDQG'LJLWDO 6LJQDWXUHZLWK'DWH :,1-:$* :DWHU%EO2LO%EO ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGFRUUHFWWRWKHEHVWRIP\NQRZOHGJH .DWKHULQH2 &RQQRU2SHUDWLRQV(QJLQHHU NDWKHULQHRFRQQRU#KLOFRUSFRP 'DQ0DUORZH$6&7HDP2SHUDWLRQV0DQDJHU W )UD 2 $ 3* 5 J )RUP5HYLVHG6XEPLW:LWKLQGD\VRI2SHUDWLRQV By Samantha Carlisle at 2:47 pm, Dec 09, 2021 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH BJM 01/12/22 RBDMS HEW 12/9/2021 & 321-118 bjm SFD 12/15/2021 DSR-12/10/21 1 Winston, Hugh E (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, November 8, 2021 5:38 PM To:Katherine O'connor Cc:Juanita Lovett; Roby, David S (OGC) Subject:RE: [EXTERNAL] RE: K-17 (PTD: 173-001) ESP Swap Sundry Hi Katherine. You have verbal approval to run the kill string as you requested in your email below. Please follow up with a Sundry submittal for the Change to Approved permit within 3 days per 20 AAC 25.507. Please include the following: 1. A description of the work you’ve completed to date and the reason for running the kill string. 2. Include a written commitment in the Sundry to either repair the well or place a downhole plug above the perfs/damaged zone within 1 year of completion of operations. 3. Submit a single 10‐404 to cover both Sundries within 30 days of moving the rig off the well. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent: Monday, November 8, 2021 4:19 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] RE: K‐17 (PTD: 173‐001) ESP Swap Sundry The long term future utility of this well has not yet been determined. But the best thing we can do for it right now is leave a kill string in the well; to get the well back online now is not economic as it stands because we are unable to run the ESP in the well’s current condition. We can submit a new sundry. The rig is on location now POOH w/ the work string. Thanks Katherine From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Monday, November 8, 2021 3:19 PM To: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: [EXTERNAL] RE: K‐17 (PTD: 173‐001) ESP Swap Sundry Katherine, This change in plans requires a Sundry per 20 AAC 25.507. Do you have any plans to return to this well and complete it? 2 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent: Monday, November 8, 2021 12:47 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: K‐17 (PTD: 173‐001) ESP Swap Sundry Hi Bryan We will be ending this project at step 6 and running a 1200‐1500’ 4.5” kill string in the well. This morning during the cleanout we found ratty casing and potentially exited the casing during the cleanout @ ±10740’ MD. That depth is within the Middle Kenai G oil pool (CO80). The well will be left with KWF in it. Thanks Katherine O’Connor CIO Operations Engineer Katherine.oconnor@hilcorp.com W: (907) 777‐8376 C: (214) 684‐7400 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. 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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. ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϭϵͬϮϭ ϭϭͬϭϬͬϮϭ ŽŶƚ͘ƚƋĨůĂŶŐĞƐŽŶƐƚĂĐŬ͕ŝŶƐƚĂůůĐŚŽŬĞΘŬŝůůůŝŶĞƐ͕ŝŶƐƚĂůůĐŝƌĐƵůĂƚŝŶŐƐƉŽŽů͕ŝŶƐƚĂůůƌŝŐĨůŽŽƌ͕ƐƚĂŝƌƐΘŚĂŶĚƌĂŝůƐ͕ƌͬƵĂĐĐƵŵƵůĂƚŽƌ ůŝŶĞƐ͕ŝŶƐƚĂůůďĞĂǀĞƌƐůŝĚĞ͘ZͬhƚĞƐƚĞƋ͕ŝŶƐƚĂůůǁŝŶƚĞƌŝǌĂƚŝŽŶ͕ŵͬƵϯϭͬϮΗΘϰϭͬϮΗƚĞƐƚũŽŝŶƚΖƐ͘/ŶƐƚĂůůƚĞƐƚũŽŝŶƚ͕&ůŽŽĚKW͕ ƉĞƌĨŽƌŵĞĚƐŚĞůůƚĞƐƚĨĂŝůĞĚĚƵĞƚŽůĞĂŬŝŶŐƚĞƐƚŚŽƐĞ͕ƌĞƉůĂĐĞĚŚŽƐĞĂŶĚƐŚĞůůƚĞƐƚǁĂƐŐŽŽĚ͘WĞƌĨŽƌŵĞĚKWƚĞƐƚǁͬϯϭͬϮΗΘϰ ϭͬϮΗd:͕ƉĞƌƐƵŶĚƌǇĂƐĨŽůůŽǁŝŶŐ͗ŶŶƵůĂƌϮϱϬͬϯϬϬϬƉƐŝ͕ZĂŵƐϮϱϬͲϯϬϬϬƉƐŝ͕sĂůǀĞƐϮϱϬͲϯϬϬϬƉƐŝ͕ĐŚĂƌƚĞĚůŽǁͬŚŝŐŚĨŽƌϱŵŝŶƐ͘ WĞƌĨŽƌŵĞĚ<ŽŽŵĞǇĚƌĂǁĚŽǁŶƚĞƐƚĞĚŐĂƐĚĞƚĞĐƚŝŽŶ͘EŽĨĂŝůƵƌĞƐǁĞƌĞƌĞĐŽƌĚĞĚ͘K'ǁŝƚŶĞƐƐǁĂŝǀĞĚďǇ:ŝŵZĞŐŐŽŶ ϭϬͬϭϴͬϮϭΛϬϴ͗ϰϮŚƌƐ͘ZͬKWƚĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚ͕WͬhdͲďĂƌ͕ĐŚĞĐŬĞĚĨŽƌƚďŐƉƌĞƐƐƵƌĞ͕ƚďŐƐƚĂƚŝĐ͕ƉƵůůĞĚWs͕DͬhϰͲϭͬϮΗ ůĂŶĚŝŶŐũŽŝŶƚ͘Zͬh<Ͳ>͕Dͬh>ĂŶĚdƵďŝŶŐƉƵŶĐŚ͕Z/,ĂŶĚƉƵŶĐŚĞĚŚŽůĞƐΛϵ͕ϲϯϱΖ;ϭϬŚŽůĞƐͿ͘WKK,͘ ϭϬͬϮϭͬϮϬϮϭͲdŚƵƌƐĚĂǇ ŽŶƚ͘WKK,ǁͬĞͲůŝŶĞ͕ĂůůƐŚŽƚƐĨŝƌĞĚŽŶŚŽůĞƉƵŶĐŚ͕ƌͬĚĞͲůŝŶĞ͘ZͬhďƌĞĂŬĐŝƌĐƵůĂƚŝŽŶ͕ƐƚĂŐĞƵƉƚͬϯϭͬϮWDϭϭϱϬƉƐŝ͕ƐŚƵƚ ĚŽǁŶƚŽƌĞƉĂŝƌůĞĂŬŽŶĐŝƌĐƵůĂƚŝŶŐůŝŶĞ͕ĐŽŵĞďĂĐŬŽŶǁŝƚŚƉƵŵƉƉƌĞƐƐƵƌĞĚƵƉƚͬϭϱϬϬƉƐŝΛϭ͘ϱWD͕ƌŽĐŬĨůƵŝĚΘďƌŝŶŐƉƵŵƉ ďĂĐŬŽŶ͘ŝƌĐƵůĂƚĞΛϭ͘ϮͲϭ͘ϰďƉŵϭϲϮϬͲϭϳϱϬƉƐŝ͘ƚŝůůƌĞƚƵƌŶƐĐůĞĂŶĞĚƵƉ͕ĂƚƚĞŵƉƚƚŽĐůĞĂƌƌĞƐƚƌŝĐƚŝŽŶĂŐĂŝŶǁŝƚŚŶŽůƵĐŬ͘Z/,ǁͬ ĞͲůŝŶĞƉƵŶĐŚ͕ƐĞƚƚŽƉƐŚŽƚΛϵϰϵϬΖĨŝƌĞƉƵŶĐŚ;ϭϬŚŽůĞͿ͕ŐŽŽĚŝŶĚŝĐĂƚŝŽŶŐƵŶĨŝƌĞĚ͕WKK,͕ĂůůƐŚŽƚƐĨŝƌĞĚ͘ƌĞĂŬĐŝƌĐƵůĂƚŝŽŶ͕Ϯ ďƉŵ͕ϭϱϬϬƉƐŝ͕ĐŽŶƚ͘h͕ƐͬĚŵŽŶŝƚŽƌǁĞůůƵͲƚƵďŝŶŐΘĚŝƌƚǇ͘ŽŶƚ͘ĐŝƌĐƵůĂƚŝŶŐϭϳϱďďůƐ͕ĐůĞĂŶ͕ƐͬĚŵŽŶŝƚŽƌǁĞůůϯϬŵŝŶŐŽŽĚ͘ ZͬĐŝƌĐƵůĂƚŝŶŐůŝŶĞƐ͕ƌͬƵĞƐƉƉƵůůŝŶŐĞƋ͘K>^͕ŽƉĞŶ/ƉƵůůĞĚ,ĂŶŐĞƌŽĨĨƐĞĂƚΛϭϱϮŬ͕ŽďƐĞƌǀĞĚϮͲϯŬĚƌĂŐĐŽŵŝŶŐŽĨĨďŽƚƚŽŵ͕ ƉƵůůĞĚŚĂŶŐĞƌƚŽƌŝŐĨůŽŽƌ͕ĚĞͲĐŽŵƉůĞƚĞĚĂŶĚ>ͬĚŚĂŶŐĞƌ͕ĨŝůůĞĚŚŽůĞǁŝƚŚϮϱďďůƐŽĨ&/t͕ϭϲďƉŚƐƚĂƚŝĐůŽƐƐĞƐ͘WKK,Ĩͬϵ͕ϴϯϰΖ ƚͬϳ͕ϬϬϬΖ͕>ͬĚϯũŽŝŶƚƐĂŶĚƉƵůůĞĚĐĂďůĞƚŚƌŽƵŐŚƐŚĞĂǀĞƚŽƐƉŽŽůĞƌ͘ŽŶƚŝŶƵĞ>ͬĚϰͲϭͬϮΗ^WĐŽŵƉůĞƚŝŽŶ͕ƌĞŵŽǀŝŶŐĐůĂŵƉƐ͕ ƐƉŽŽůŝŶŐĐĂďůĞĂŶĚĐĂƉ͕ĨŝůůŝŶŐŚŽůĞĞǀĞƌǇϭϱũƚƐǁͬ&/t͘dŽƚĂůŽĨϵϬũƚƐ>ͬĚΛƌĞƉŽƌƚƚŝŵĞ͘ ϭϬͬϮϬͬϮϬϮϭͲtĞĚŶĞƐĚĂǇ ZͬhƉƵŵƉΘƉŝƚƐ͕ĨŝůůƉŝƚƐǁͬ&/t͕ƐƚĂŶĚDĂƐƚ͘WƵŵƉŽŶ<Ͳϭϳ͕ďƌĞĂŬĐŝƌĐƵůĂƚŝŽŶŐĞƚƚŝŶŐŽŝůƌĞƚƵƌŶƐ͕ĐŽŶƚ͘ƉƵŵƉŝŶŐ͘ŽŶƚ͘ƌŝŐŐŝŶŐ ƵƉ͕ƐƚƌŝŶŐƵƉůŝŶĞƐŝŶŵĂƐƚ͕ƉŽǁĞƌƵƉĞůĞĐƚƌŝĐĂůďĂŶŐďŽĂƌĚ͕ƉůƵŐŝŶĞƋ͘ΘĐŚĞĐŬƌŽƚĂƚŝŽŶ͘ŽŶƚŝŶƵĞĚĐŝƌĐƵůĂƚŝŶŐǁĞůůƚĂŬŝŶŐ ƌĞƚƵƌŶƐƚŽƉƌŽĚƵĐƚŝŽŶ͕ƐĐŽƉĞŽƵƚĚĞƌƌŝĐŬĂŶĚƐĞĐƵƌĞĚŐƵǇůŝŶĞƐĂŶĚŝŶƐƉĞĐƚĞĚ͕ŚŽŽŬƵƉƐƵƉĞƌĐŚŽŬĞ͘^ͬƉƵŵƉŝŶŐĂŶĚ ŵŽŶŝƚŽƌĞĚǁĞůůĨŽƌϯϬŵŝŶƐ͕/ͬdďŐƐƚĂƚŝĐ͕ƐƚĂŐĞĚƚŽŽůƐƚŽŶŝƉƉůĞĚŽǁŶƚƌĞĞ͘ZͬĚĐŝƌĐƵůĂƚŝŶŐůŝŶĞƐĨƌŽŵ<Ͳϭϳ͕^ĞƚWs͕ƌĞŵŽǀĞĚ ^^sĂŶĚĨůŽǁůŝŶĞ͘EͬdƌĞĞĂŶĚĨůǇŽƵƚŽĨǁĞůůŚŽƵƐĞ͘/ŶƐƉĞĐƚĞĚůŝĨƚŝŶŐƚŚƌĞĂĚƐŽŶŚĂŶŐĞƌ͕DͬƵďůĂŶŬŝŶŐƐƵďƚŽŚĂŶŐĞƌƚŚƌĞĂĚƐ͘ EͬhKWΖƐ͕/ŶƐƚĂůůĞĚƌŝƐĞƌ͕ƐĞƚŝŶĂŶĚƐƚĂƌƚƚŽƌƋƵĞŝŶŐƵƉKWƐƚĂĐŬ͘ ϭϬͬϭϵͬϮϬϮϭͲdƵĞƐĚĂǇ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ <Ͳϭϳ ϱϬͲϳϯϯͲϮϬϮϰϴͲϬϬͲϬϬ ϭϳϯͲϬϬϭ ϭϬͬϮϮͬϮϬϮϭͲ&ƌŝĚĂǇ ŽŶƚ͕WKK,ůͬĚϰϭͬϮΗϭϮ͘ϲη/dĐŽŵƉůĞƚŝŽŶĨͬϳϬϬϬΖƚͬϰϴϱϵΖ͕ĨůƵŝĚůŽƐƐΛϭϮW,͘^ǁĂƉŽƵƚĐĂďůĞƐƉŽŽů͕ďĂĐŬůŽĂĚďŽĂƚǁŝƚŚϮ ƉŝƉĞƌĂĐŬƐŽĨƉƵůůĞĚϰϭͬϮΖƚƵďŝŶŐΘƵŶůŽĂĚďŽĂƚǁŝƚŚϯϭͬϮΗǁŬƐƚƌŝŶŐ͘ŽŶƚ͕WKK,ůͬĚϰϭͬϮΗϭϮ͘ϲη/dĐŽŵƉůĞƚŝŽŶĨͬϰϴϱϵΖ ƚͬϮϭϵΖ͕ĨůƵŝĚůŽƐƐΛϭϮ,W͘:ƵƐƚĂĨƚĞƌƌĞŵŽǀŝŶŐĐĂďůĞƐƉůŝĐĞĐůĂŵƉĨͬƚŚĞůĂƐƚƚƵďŝŶŐũƚƚŚĞƉŝŐƚĂŝůƐƉůŝĐĞŽŶƚŚĞ^WĐĂďůĞƉƵůůĞĚ ĂƉĂƌƚĂŶĚƚŚĞĚƵĂůĞŶĐĂƉƐƵůĂƚĞĚĐĂƉůŝŶĞĨƌĞĞƐƉŽŽůĞĚŝŶƚŚĞŚŽůĞƌŽƵŐŚůǇΕϭϱϬϬΖĂŶĚƐƚŽƉƉĞĚ͘ƵƚƚŚĞĐĂƉƐƚƌŝŶŐĂƚƚŚĞƐůŝƉƐ͘ ZͬĚƚŚĞĐĂďůĞƐŚĞĂǀĞ͕ĐůĞĂƌĞĚƌŝŐĨůŽŽƌ͘tĞůĚĞƌĨĂďƌŝĐĂƚŝŶŐĐůĂŵƉƐƚŽƐĞĐƵƌĞƚŚĞĐĂƉůŝŶĞƐĨƌŽŵĨĂůůŝŶŐĚŽǁŶŚŽůĞďĞĨŽƌĞƉƵůůŝŶŐ ƚŚĞƉƵŵƉƚŽƐƵƌĨĂĐĞƚŽƐĞĞǁŚĞƌĞƚŚĞĂƐƐĞŵďůǇƉĂƌƚĞĚ͘ůĂŵƉĞĚĐŽŶƚƌŽůůŝŶĞƉƵůůĞĚƚŚĞ^WĂƐƐĞŵďůǇƚŽƐƵƌĨĂĐĞ͕ϮŶĚƉƵŵƉ ƐĞĐƚŝŽŶŝƐǁĞƌĞŝƚƉĂƌƚĞĚ͘ĂƉͲƐƚƌŝŶŐĂŶĚĐĂďůĞŚĂŶŐŝŶŐďĞůŽǁƉĂƌƚĚŽǁŶŚŽůĞ͘ ŽŶƚŝŶƵĞ>ͬĚϰͲϭͬϮΗ^WĐŽŵƉůĞƚŝŽŶ͕ ŽŶƚ͕WKK,ůͬĚϰϭͬϮΗϭϮ͘ϲη/dĐŽŵƉůĞƚŝŽŶĨͬϳϬϬϬΖƚͬϰϴϱϵΖ͕Ĩ WĞƌĨŽƌŵĞĚKWƚĞƐƚǁͬϯϭͬϮΗΘϰ ϭͬϮΗd:͕ƉĞƌƐƵŶĚƌǇĂƐĨŽůůŽǁŝŶŐ͗ŶŶƵůĂƌϮϱϬͬϯϬϬϬƉƐŝ͕ZĂŵƐϮϱϬͲϯϬϬϬƉƐŝ͕ Z/,ĂŶĚƉƵŶĐŚĞĚŚŽůĞƐΛϵ͕ϲϯϱΖ;ϭϬŚŽůĞƐͿ ESP assembly appears to have parted. ϮŶĚƉƵŵƉ ƐĞĐƚŝŽŶŝƐǁĞƌĞŝƚƉĂƌƚĞĚ͘ĂƉͲƐƚƌŝŶŐĂŶĚĐĂďůĞŚĂŶŐŝŶŐďĞůŽǁƉĂƌƚĚŽǁŶŚŽůĞ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϭϵͬϮϭ ϭϭͬϭϬͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ <Ͳϭϳ ϱϬͲϳϯϯͲϮϬϮϰϴͲϬϬͲϬϬ ϭϳϯͲϬϬϭ ϭϬͬϮϯͬϮϬϮϭͲ^ĂƚƵƌĚĂǇ >ͬůĂƐƚũŽŝŶƚΘƵƉƉĞƌƉƵŵƉĂƐƐǇ͕ƌͬƵƐƚĂŶĚΘƉƵůůƐƚƌŝƉƉĞĚĚƵĂůĐŽŶƚƌŽůůŝŶĞKK,͕ƌĞĐŽǀĞƌĞĚΕϳϵϬΖŽĨĚƵĂůĐŽŶƚƌŽůůŝŶĞ͕ĞŶĚƐ ĂƉƉĞĂƌĞĚƚŽŚĂǀĞƉĂƌƚĞĚ͘ůĞĂŶΘĐůĞĂƌĨůŽŽƌ͕ƌͬĚ^WƉƵůůŝŶŐĞƋ͘,ŽƵƐĞŬĞĞƉŝŶŐǁŚŝůĞǁĂŝƚŝŶŐŽŶŽĂƚǁŝƚŚǁͬůΘĨŝƐŚŝŶŐƚŽŽůƐ͕ ůŽƐƐƌĂƚĞϵW,͘hŶůŽĂĚďŽĂƚǁͬǁͬůƵŶŝƚΘƐƚĂƌƚƌŝŐƵƉ͘ŽŶƚ͘ŽĨĨůŽĂĚΘďĂĐŬůŽĂĚďŽĂƚ͘Z/,ǁͬϴΗ>/ƚŽϭϬϱϱϴΖƐĞƚĚŽǁŶ͕ǁŬ ŽŶĞƚŝŵĞ͕WKK,͕ŚĂĚƐƉŽƚƚĞĚŝŵƉƌĞƐƐŝŽŶƐďƵƚŶŽƚƚŚĞƚŽƉŽĨƉƵŵƉ͘Z/,ǁͬϰϭͬϮΗŵĂŐŶĞƚ͕ƚĂŐŐĞĚΛϭϬϱϱϴΖ͕ǁŽƌŬĞĚǁŝƚŚůŝƚƚůĞ ĞĨĨŽƌƚƚŽϭϬϱϳϮΖWKK,͕ŵĂŐŶĞƚŚĂĚƐŽŵĞŵĞƚĂůĨŝŶĞƐďƵƚŶŽĐĂďůĞ͕ĐůĂŵƉƐŽƌĞƐƉĐŽŵƉŽŶĞŶƚƐƌĞĐŽǀĞƌĞĚ͘Z/,ǁͬϱ͘ϵϬΗ ĐĞŶƚƌĂůŝǌĞƌĂŶĚϱΗ>/ƚĂŐŐĞĚΛϭϬ͕ϱϳϮΖ͕ǁŽƌŬĞĚĚŽǁŶƚŽϭϬ͕ϱϳϲΖ͕ǁŽƌŬĞĚŽŶĞƚŝŵĞ͕ϮϱϬůďŽǀĞƌƉƵůůĐŽŵŝŶŐŽĨĨ͕WKK,͕ŶŽ ŝŵƉƌĞƐƐŝŽŶ͘>ͬĚϱ͘ϵϬΗĐĞŶƚƌĂůŝǌĞƌ͕Z/,ǁͬϱΗ>/ƚĂŐŐĞĚΛϭϬ͕ϱϳϮΖ͕ǁŽƌŬĞĚĚŽǁŶƚŽϭϬ͕ϱϳϲΖ͕ǁŽƌŬŝŶŐŽŶĞƚŝŵĞ͕WKK,͘Z/,ǁͬϴΗ >/ƚĂŐŐĞĚΛϭϬ͕ϱϱϴΖ͕ǁŽƌŬĞĚƚǁŽƚŝŵĞƐ͕WKK,͕ŶŽŝŵƉƌĞƐƐŝŽŶ͕Zͬ^>͘ůĞĂŶĂŶĚĐůĞĂƌƌŝŐĨůŽŽƌ͕ͬŽŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚ͘Dͬh ,ηϭĂƐĨŽůůŽǁŝŶŐ͗ ƵůůĚŽŐ^ĐƌĞǁ^ƉĞĂƌϳͲϭͬϮΗKǆϯΗ/͕yK^ƵďϯϭͬϮΗ/&ǆϰϭͬϮΗ/&ǆW͕ƵŵƉĞƌĂŶĚKŝů:ĂƌƐϰϯͬϰΗKǆϮϭͬϰΗ/ ^ƉŝƌĂůΖƐϰͲϰϯͬϰΗKǆϮϯͬϴΗ/͕ĐĐĞůĞƌĂƚŽƌ:ĂƌϰͲϯͬϰΗKǆϮϭͬϰΗ/͕yK^ƵďϯϭͬϮΗW,ϲǆϯϭͬϮΗ/&ǆW ,>ĞŶŐƚŚсϭϲϯ͘ϱϭ͘d/,ǁͬ,͕ƉŝĐŬŝŶŐƵƉϯϭͬϮΗϭϮ͘ϵϱηWͲϭϭϬW,ͲϲtŽƌŬͲƐƚƌŝŶŐĨͬϭϲϯΖƚͬϮ͕ϯϳϲΖ͘ϳϬũŽŝŶƚŝŶƚŚĞŚŽůĞĂƚ ƌĞƉŽƌƚŝŶŐƚŝŵĞ͘ ϭϬͬϮϰͬϮϬϮϭͲ^ƵŶĚĂǇ ŽŶƚŝŶƵĞĚd/,ǁͬ,ηϭ͕ƉŝĐŬŝŶŐƵƉϯͲϭͬϮΗϭϮ͘ϵϱηWͲϭϭϬǁŽƌŬƐƚƌŝŶŐƚͬϭϬ͕ϱϱϳΖ͕WhtϭϯϬŬͬ^KtϳϬŬ͘WͬhũƚηϯϯϲĂŶĚƚĂŐŐĞĚ ΛϭϬ͕ϱϲϱΖǁͬϭϬŬĚŶ͕WͬhŽĨĨƚĂŐ͕ŵĂĚĞϮƌŽƵŶĚƐŽĨZ,dǁŽƌŬŝŶŐƚŽƌƋƵĞĚŽǁŶĞŶŐĂŐŝŶŐĨŝƐŚ͕ƌĞůĞĂƐĞĚƚŽƌƋƵĞŐŽƚϭͬϮƌŽƵŶĚƐ ďĂĐŬ͕ƌĞƉĞĂƚĞĚƐĞĞŶǁĞŝŐŚƚŝŶĐƌĞĂƐĞ͘DĂĚĞWͬhǁŝƚŚϯͲϱŬŽǀĞƌƉƵůůĂŶĚǁƚĨĞůůďĂĐŬƚŽƉƌĞǀŝŽƵƐWhtϭϯϬŬ͘WKK,ƐƚĂŶĚŝŶŐ ďĂĐŬϯϭͬϮΗǁŽƌŬƐƚƌŝŶŐĨͬϭϬ͕ϱϲϱΖƚͬ,ηϭ͘>ͬĐĐĞůĞƌĂƚŽƌ:ĂƌƐ͕ƐƚŽŽĚďĂĐŬϮƐƚĂŶĚƐŽĨƐ͕ƉƵůůĞĚKŝůΘƵŵƉĞƌ:ĂƌƐĂŶĚ ƵůůĚŽŐƐƉĞĂƌƚŽƌŝŐĨůŽŽƌͲƌĞĐŽǀĞƌĞĚƉĂƌƚŽĨĂĐĂŶŶŽŶĐůĂŵƉ͘>ͬ:ĂƌƐĂŶĚƵůůĚŽŐ͘^ůŝƉĂŶĚĐƵƚĚƌŝůůůŝŶĞ͕ƐĞƌǀŝĐĞƌŝŐĂƐŶĞĞĚĞĚ͘ ϭϬͬϮϱͬϮϬϮϭͲDŽŶĚĂǇ &ŝŶŝƐŚƵƚΘƐůŝƉĚƌŝůůůŝŶĞ͘^ĞƌǀŝĐĞƌŝŐΘƌĞƉĂŝƌƐŚŝĨƚůĞǀĞƌŽŶϲϬϬ'ŝůůƐ͕ƐĞƌǀŝĐĞƐĂŵĞ͘Wͬh,ηϮͲϴϭͬϮΗŵŝůů yK^ƵďϯϭͬϮΗ/&ǆϰϭͬϮΗ/&ǆW͕ƵŵƉĞƌĂŶĚKŝů:ĂƌƐϰϯͬϰΗKǆϮϭͬϰΗ/͕^ƉŝƌĂůΖƐϰͲϰϯͬϰΗKǆϮϯͬϴΗ/͕ĐĐĞůĞƌĂƚŽƌ:Ăƌ ϰͲϯͬϰΗKǆϮϭͬϰΗ/͕yK^ƵďϯϭͬϮΗW,ϲǆϯϭͬϮΗ/&ǆW͕,>ĞŶŐƚŚсϭϲϭ͘ϰϯ͘dŝŚǁͬϭϲϲƐƚĂŶĚƐŽĨϯϭͬϮΗW,ϲǁŬƐƚƌŝŶŐ ƚͬϭϬϰϲϰΖWhtϭϯϮŬ͕^KtϲϲŬ͘ZͬhƉŽǁĞƌƐǁŝǀĞů͕ůĞǀĞůĞĚƌŝŐƚŽĐĞŶƚĞƌŚŽůĞ͕ŝŶƐƚĂůůĞĚĐŝƌĐƵůĂƚŝŶŐƌƵďďĞƌ͕ƚŽƌƋƵĞ<ĞůůǇǀĂůǀĞĂŶĚ yKƐƵď͕^ĞƚƚŽƌƋƵĞΛϳ͕ϱϬϬďůͬĨƚ͘ƌŽŬĞĐŝƌĐƵůĂƚŝŽŶ͕</,ƚĂŐŐĞĚƐƚĂƌƚŵŝůůŝŶŐͬǁĂƐŚŝŶŐΛϭϬ͕ϱϲϬΖ͕ƌĞǀĐŝƌĐΛϯďƉŵͬϰϮϬƉƐŝ͕ƵƉǁƚ ϭϯϴŬ͕ĚŶϳϮŬ͕ƌŽƚǁƚ͘ϵϲŬ͕ƚƋŽĨĨϱϴϬϬ͕ƚƋŽŶϲϮͲϲϴϬϬ͕tKϯͲϱŬ͕ƚƋŝŶĐƌĞĂƐĞĚƚŽϳϬͲϳϱϬϬďŽƚŚŽŶŽƌŽĨĨ͕ŵĂŬĞƐĞǀĞƌĂůϯϬΖ ƉŝĐŬƵƉ͕ďƌĞĂŬƵƉũƵŶŬĂƌŽƵŶĚŵŝůůƚŽƌĞŐĂŝŶƚƋ͘ŽŶƚŝŶƵĞDŝůůŝŶŐͬǁĂƐŚĨͬϭϬϱϲϬƚͬϭϬϱϳϲΖ͕ƌĞǀĐŝƌĐΛϯďƉŵͬϰϬϬƉƐŝ͕ƵƉǁƚϭϯϴŬ͕ ĚŶϳϮŬ͕ƌŽƚǁƚ͘ϵϲŬ͕ƚƋŽĨĨϱϴϬϬ͕ƚƋŽŶϲϮͲϳϱϬϬ͕tKϯͲϱŬ͕ƌĞƚƵƌŶƐĂƚƚŚĞƐŚĂŬĞƌƐƐĐĂůĞĂŶĚƌƵďďĞƌƉŝĞĐĞƐ͕ϮϱďƉŚůŽƐƐĞƐ͘ ŽŶƚŝŶƵĞŵŝůůŝŶŐŽŶŽďƐƚƌƵĐƚŝŽŶΛϭϬ͕ϱϳϲΖ͕ƌĞǀĐŝƌĐϯďƉŵͬϰϬϬƉƐŝ͕tKϱͲϭϬŬ͕ƚƋŽŶϳϬͲϳϱϬϬ͕ŽďƐĞƌǀĞĚƐĞǀĞƌĂůƐƚĂůůƐĂŶĚŶŽƚ ŵĂŬŝŶŐŚŽůĞ͕ĚĞƚĞƌŵŝŶĞǁĞĂƌĞĂƚƚŚĞƚŽƉŽĨƚŚĞƉĂƌƚĞĚ^WƉƵŵƉ͘WͬhϭϬΖŽĨĨŽĨĨŝƐŚĂŶĚͬͬh͕ƉƌĞƉƚŽ>ͬƉŽǁĞƌƐǁŝǀĞůĂŶĚ WKK,͘ Wͬh,ηϮͲϴϭͬϮΗŵŝůů ĚĞƚĞƌŵŝŶĞǁĞĂƌĞĂƚ ƚŚĞƚŽƉŽĨƚŚĞƉĂƌƚĞĚ^WƉƵŵƉ͘ ĂƉƉĞĂƌĞĚƚŽŚĂǀĞƉĂƌƚĞĚ͘ ƌĞĐŽǀĞƌĞĚΕϳϵϬΖŽĨĚƵĂůĐŽŶƚƌŽůůŝŶĞ͕ ŽŶƚŝŶƵĞDŝůůŝŶŐͬǁĂƐŚĨͬϭϬϱϲϬƚͬϭϬϱϳϲΖ͕ ƌĞƚƵƌŶƐĂƚƚŚĞƐŚĂŬĞƌƐƐĐĂůĞĂŶĚƌƵďďĞƌƉŝĞĐĞƐ͕ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϭϵͬϮϭ ϭϭͬϭϬͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ <Ͳϭϳ ϱϬͲϳϯϯͲϮϬϮϰϴͲϬϬͲϬϬ ϭϳϯͲϬϬϭ ϭϬͬϮϲͬϮϬϮϭͲdƵĞƐĚĂǇ &ŝŶŝƐŚh͕ůͬĚƐŝŶŐůĞ͕ƌͬĚƉŽǁĞƌƐǁŝǀĞůΘĐŝƌĐƵůĂƚŝŶŐŚĞĂĚ͘WͬhŚĂŶĚůŝŶŐĞƋ͘WKK,ƐƚĂŶĚŝŶŐďĂĐŬϯϭͬϮΗǁŬƐƚƌŝŶŐĨͬϭϬϱϮϴΖ͘>ͬ ĂĐĐĞůĞƌĂƚŽƌ͕ƐƚĂŶĚďĂĐŬĚƌŝůůĐŽůůĂƌƐ͕>ͬ:ĂƌƐĂŶĚůĂĚĞĚDŝůů͘DŝůůƐŚŽǁƐĂǁĞĂƌƉĂƚƚĞƌŶĨƌŽŵƌŽƚĂƚŝŶŐŽŶƚŽƉŽĨƚŚĞƉĂƌƚĞĚ ƉƵŵƉƐŚĂĨƚ͕ĨŽƵƌŽĨƚŚĞĐŝƌĐƉŽƌƚƐƉůƵŐŐĞĚŽĨĨǁŝƚŚƌƵďďĞƌ͘,ŽƵƐĞŬĞĞƉŝŶŐĂŶĚŵĂŝŶƚĞŶĂŶĐĞ͕ĚŝƐĐƵƐƐĞĚƉůĂŶĨŽƌǁĂƌĚǁŝƚŚƚŽǁŶ͘ DŽŶŝƚŽƌǁĞůůƐƚĂƚŝĐůŽƐƐƌĂƚĞΛϮďƉŚ͘Wͬh,ηϯϲϱͬϴΗƵƚůŝƉK^ǁͬϱϯͬϴ^ƉŝƌĂů'ƌĂƉƉůĞĂƚĐŚ͕ďůWŝŶyK^ƵďϯϭͬϮΗ/&ǆϯ ϭͬϮΗZĞŐ͕ϯͲ:ƵŶŬĂƐŬĞƚƐϰϯͬϰΗKǆϭϭͬϮΗ/͕ďůŽǆyK^ƵďϯϭͬϮΗZĞŐǆϯϭͬϮΗ/&͕ƵŵƉĞƌĂŶĚKŝů:ĂƌƐϰϯͬϰΗKǆϮϭͬϰΗ /͕^ƉŝƌĂůΖƐϰͲϰϯͬϰΗKǆϮϯͬϴΗ/͕ ĐĐĞůĞƌĂƚŽƌ:ĂƌϰͲϯͬϰΗKǆϮϭͬϰΗ/͕yK^ƵďϯϭͬϮΗW,ϲǆϯϭͬϮΗ/&ǆW͕,>ĞŶŐƚŚсϭϳϮ͘ϵϮ͘d/,ǁͬϯϭͬϮΗW,ϲǁŽƌŬƐƚƌŝŶŐ ĨƌŽŵĚĞƌƌŝĐŬ͕ĨͬϭϳϮΖƚͬϭϬ͕ϱϲϳΖĂƚƌĞƉŽƌƚƚŝŵĞ͘ ϭϬͬϮϳͬϮϬϮϭͲtĞĚŶĞƐĚĂǇ ^ƉĂĐĞŽƵƚ͕d/,ΘǁŬŽǀĞƌƚŽĨΛϭϬ͕ϱϳϲΖ͕ƵƉǁƚϭϮϴŬ͕ĚŶǁƚϲϲŬ͕ƉͬƵƚͬϱŬŽǀĞƌΘďůĞĞĚũĂƌƐ͕ĐĂŵĞĨƌĞĞĨƌŽŵĨŝƐŚ͕ƌĞͲĞŶŐĂŐĞĨŝƐŚ ďůĞĞĚũĂƌƐŽĨĨ͕ƉͬƵƐƚĂŐŝŶŐƵƉϭϲϬŬ͕;Ϯϱ<ŽǀĞƌƉƵůůͿĐĂŵĞĨƌĞĞĨƌŽŵĨŝƐŚ͕ŵĂĚĞŽŶĞŵŽƌĞĂƚƚĞŵƉƚƐƚĂĐŬŝŶŐŵŽƌĞǁĞŝŐŚƚĚŽǁŶŝŶ ĂƚƚĞŵƉƚƚŽŐĞƚďĞƚƚĞƌĞŶŐĂŐĞŵĞŶƚ;ďĞůŝĞǀĞǁĞĂƌĞŶŽƚŐĞƚƚŝŶŐĨƵůůĞŶŐĂŐĞŵĞŶƚǁŝƚŚŐƌĂƉƉůĞͿǁŝƚŚƐĂŵĞƌĞƐƵůƚƐ͘WKK, ƐƚĂŶĚŝŶŐďĂĐŬϯͲϭͬϮΗW,ϲǁŬƐƚƌŝŶŐ͕͘^ƚĂŶĚďĂĐŬĚƌŝůůĐŽůůĂƌƐ͕ůͬĚ,͕ŵĂƌŬƐŽŶůǇŐŽŝŶŐĂĨĞǁŝŶĐŚĞƐŝŶƐŝĚĞK^ďŽǁů͘ůĞĂƌĞĚ ĂŶĚĐůĞĂƌĞĚĨůŽŽƌ͕ĚƌĂŝŶĞĚƐƚĂĐŬĂŶĚĨŝƐŚĞĚϮΖƉŝĞĐĞŽĨĨůĂƚƉĂĐŬƐŚĞĂǀŝŶŐŽƵƚŽĨƌŝƐĞƌ͘ZͬhKWƚĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚ͕ĨůŽŽĚĞĚKW ĂŶĚǁŽƌŬĞĚĂŝƌŽƵƚŽĨƐǇƐƚĞŵ͕^ŚĞůůƚĞƐƚĞĚϮϱϬͲϯ͕ϬϬϬƉƐŝ͘dĞƐƚĞĚKWΖƐƉĞƌ^ƵŶĚƌǇĂƐĨŽůůŽǁŝŶŐ͗ŶŶƵůĂƌϮϬϱͲϯ͕ϬϬϬƉƐŝ͕ZĂŵƐ ϮϱϬͲϯ͕ϬϬϬƉƐŝ͕sĂůǀĞƐϮϱϬͲϯ͕ϬϬϬƉƐŝ͕ƉĞƌĨŽƌŵĞĚ<ŽŽŵĞǇƌĂǁĚŽǁŶ͘ϯͲϭͬϮΗΘϰͲϭͬϮΗdĞƐƚ:ŽŝŶƚƐƵƐĞĚ͕EŽĨĂŝůƵƌĞƐƌĞĐŽƌĚĞĚ͕ ǁŝƚŶĞƐƐǁĂƐǁĂŝǀĞĚďǇ:ŝŵZĞŐŐϭϬͬϮϲͬϮϬϮϭϭϭ͗ϮϰD͘ZͬĚƚĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚĂŶĚďůŽǁůŝŶĞƐĚƌǇ͕ĐůĞĂŶĞĚŽƌŐĂŶŝǌĞĚĨůŽŽƌ͕ZͬƵ ŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚĨŽƌ,͘Wͬh,ηϰ ϴͲϯͬϴΗZŽƚĂƌǇ^ŚŽĞǁͬϱͲϭͬϮΗ/с;ϰ͘ϰϮΖͿ ϴͲϭͬϴ͟Ăŵ&ŝĞůĚƵƐŚŝŶŐ<,dϰЪ͟/& yK^ƵďϯͲϭͬϮΗ/&ǆϰͲϭͬϮΗ/& ďůWŝŶyK^ƵďϯЪ/&ǆϯЪ͟ZĞŐ ϯͲ:ƵŶŬĂƐŬĞƚƐϰͲϯͬϰΗKǆϭͲϭͬϮΗ/ ďůŽǆyK^ƵďϯͲϭͬϮΗZĞŐǆϯͲϭͬϮΗ/& ƵŵƉĞƌĂŶĚKŝů:ĂƌƐϰͲϯͬϰΗKǆϮϭͬϰΗ/ ^ƉŝƌĂůΖƐϰͲϰͲϯͬϰΗKǆϮϯͬϴΗ/ ĐĐĞůĞƌĂƚŽƌ:ĂƌϰͲϯͬϰΗKǆϮϭͬϰΗ/ yK^ƵďϯͲϭͬϮΗW,ϲǆϯͲϭͬϮΗ/&ǆW ,>ĞŶŐƚŚсϭϳϳ͘ϵϰ DŝůůƐŚŽǁƐĂǁĞĂƌƉĂƚƚĞƌŶĨƌŽŵƌŽƚĂƚŝŶŐŽŶƚŽƉŽĨƚŚĞƉĂƌƚĞĚ ƉƵŵƉƐŚĂĨƚ͕ĨŽƵƌŽĨƚŚĞĐŝƌĐƉŽƌƚƐƉůƵŐŐĞĚŽĨĨǁŝƚŚƌƵďďĞƌ͘ dĞƐƚĞĚKWΖƐƉĞƌ^ƵŶĚƌǇĂ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϬͬϭϵͬϮϭ ϭϭͬϭϬͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ <Ͳϭϳ ϱϬͲϳϯϯͲϮϬϮϰϴͲϬϬͲϬϬ ϭϳϯͲϬϬϭ ϭϬͬϮϴͬϮϬϮϭͲdŚƵƌƐĚĂǇ ŽŶƚ͘Wͬh,ηϰ͕͘dŝŚǁͬϯͲϭͬϮΗǁŬƐƚƌŝŶŐĨƌŽŵĚĞƌƌŝĐŬƚͬϭϬ͕ϱϲϳΖ͘DͬƵWŽǁĞƌ^ǁŝǀĞůĂŶĚ<ͬƵŽŶƐŝŶŐůĞ͕ƐƚĂďƚŚƌƵĐŝƌĐƵůĂƚŝŶŐ ƌƵďďĞƌĂŶĚůŽĐŬĞĚĚŽǁŶ͘WhtϭϯϮŬ͕^KtϳϮ͕ZƚtƚϭϬϬŬ͕ZŽƚĂƚĞĚͬtĂƐŚĚŽǁŶŽǀĞƌdK&ΛϭϬ͕ϱϳϲΖƚͬϭϬ͕ϱϴϭΖ͕ƐƚŐƉƵŵƉĐŝƌĐ ůŽŶŐǁĂǇΛϮ͘ϳϱďƉŵͬϰϬϬƉƐŝ͘dƋϲ͕ϬϬϬĨƌĞĞͬϲϮͲϳϬϬϬŽŶ͕ZWDϯϬ͕ϮͲϱŬtK͘EŽͬŐŽƚŽƉƐƵďŽŶĨŝƐŚƐĞĞŝŶŐƉƵŵƉƉƌĞƐƐƵƌĞ ŝŶĐƌĞĂƐĞĚƚͬϰϲϬƉƐŝ͘ZĞĐŝƉƌŽĐĂƚĞĚƐŚŽĞŽǀĞƌĨŝƐŚƐĞǀĞƌĂůƚŝŵĞƐǁŝƚŚŶŽŝƐƐƵĞƐ͘WͬƵŽĨĨĨŝƐŚĂŶĚƌĞǀͬͬhΛϯďƉŵͬϰϯϬƉƐŝ͕ ƌĞƚƵƌŶƐƐĐĂůĞĂŶĚƌƵďďĞƌďĞĨŽƌĞĐůĞĂŶŝŶŐƵƉ͘>ͬĚƐŝŶŐůĞ͕ZͬĚƉŽǁĞƌƐǁŝǀĞůĂŶĚĐŝƌĐƵůĂƚŝŶŐůŝŶĞƐ͕͘WKK,ƐƚĂŶĚŝŶŐďĂĐŬϯͲϭͬϮΗǁŬ͘ ƐƚƌŝŶŐĨͬϭϬ͕ϱϳϲΖƚͬϭϳϳΖ͘>ͬĚĂĐĐĞůĞƌĂƚŽƌũĂƌ͕ƐƚĂŶĚďĂĐŬΖƐ͕>ͬƵŵƉĞƌΘKŝů:ĂƌƐ͕:ƵŶŬĂƐŬĞƚƐĂŶĚƌŽƚĂƌǇƐŚŽĞ͘ ϭϬͬϮϵͬϮϬϮϭͲ&ƌŝĚĂǇ &ŝŶŝƐŚďƌĞĂŬŝŶŐĚŽǁŶ,͕͘Wͬh,ηϱͲ ϳͲϯͬϴΗŽǀĞƌƐŚŽƚǁͬϱϯͬϴΗŐƌĂƉƉůĞ yK^hϰͲϭͬϮΗ/&ǆΨϰͲϭͬϮ&, yK^ƵďϯͲϭͬϮΗ/&ǆϰͲϭͬϮΗ/& ƵŵƉĞƌĂŶĚKŝů:ĂƌƐϰͲϯͬϰΗKǆϮϭͬϰΗ/ ^ƉŝƌĂůΖƐϰͲϰͲϯͬϰΗKǆϮϯͬϴΗ/ ĐĐĞůĞƌĂƚŽƌ:ĂƌϰͲϯͬϰΗKǆϮϭͬϰΗ/ yK^ƵďϯͲϭͬϮΗW,ϲǆϯͲϭͬϮΗ/&ǆW ,>ĞŶŐƚŚсϭϲϯ͘ϳϲΖ͘d/,ǁŝƚŚϯͲϭͬϮΗW,ϲǁŬƐƚƌŝŶŐƚͬϭϬ͕ϱϮϵΖ͘WhtсϭϮϴŬ^KtсϲϵŬd/,͕ĞŶŐĂŐĞĚĨŝƐŚΛϭϬ͕ϱϳϴΖ͕ďĞŐĂŶĨŝƌŝŶŐ ũĂƌǁŽƌŬŝŶŐƵƉŝŶƐƚĂŐĞƐΛϭϬŬ͕ϮϬŬ͕ϯϬŬ͕ϰϬŬŽǀĞƌƐƚƌŝŶŐǁƚ͕ŶŽŵŽǀĞŵĞŶƚ͘tŽƌŬďŽĂƚĂƌƌŝǀĞĚ͕ĂƐƐŝƐƚĐƌĂŶĞƚŽŽĨĨůŽĂĚϰƚŽƚĞƐ ŽĨƐĂĨĞĂĐŝĚ͘ZͬƵĐŝƌĐƵůĂƚŝŶŐůŝŶĞƐ͕ďƌŽŬĞĐŝƌĐϭ͘ϳϱďƉŵͬϯϴϬƉƐŝ͘ůŽƐĞĚ/ĂŶĚĞƐƚŝŶũĞĐƚŝŽŶƌĂƚĞΛϬ͘ϱďƉŵͬϱϬϬƉƐŝ͘^ƉƵŵƉ͘ WƵŵƉĞĚϭϯďďůƐŽĨ^ĂĨĞĐŝĚĚŽǁŶƚďŐ͕ĚŝƐƉůĂĐĞĚƚďŐǀŽůǁͬϳϳďďůƐŽĨ&/tΛϭ͘ϳϱďƉŵͬϯϴϬƉƐŝƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉ/͘^ƉŽƚƚŝŶŐƉŝůů ŽŶdK&ĂŶĚ/͘WͬƵϰϬŬŽǀĞƌƐƚƌŝŶŐǁƚ͕ŶŽŵŽǀĞŵĞŶƚ͕ĨŝƌĞĚũĂƌƐƐĞǀĞƌĂůƚŝŵĞƐΛϰϬŬŽǀĞƌ͕ŶŽŵŽǀĞŵĞŶƚ͘^/dďŐ͕ďƵůůŚĞĂĚϳďďůƐ ĚŽǁŶ/ƚŽĨŽƌŵĂƚŝŽŶ͕ŝŶũĞĐƚŝŽŶƌĂƚĞΛ͘ϱďƉŵͬϱϬϬƉƐŝ͘^ƉƵŵƉĂŶĚůĞƚƉƌĞƐƐƵƌĞůĞĂŬŽĨĨƚŽĨŽƌŵĂƚŝŽŶĂŶĚƐĂĨĞĂĐŝĚƐŽĂŬ ĂĐƌŽƐƐƚŚĞ^WĂƐƐĞŵďůǇ͘ŽŶƚŝŶƵĞĚǁŽƌŬŝŶŐƐƚƌŝŶŐ͕ĨŝƌŝŶŐũĂƌƐΛϰϬŬŽǀĞƌ͕ŶŽŵŽǀĞŵĞŶƚ͕ǁŽƌŬĞĚƵƉƚŽϱϬŬŽǀĞƌ͕ŶŽ ŵŽǀĞŵĞŶƚ͘WƵŵƉŝŶŐEy^ůƵďĞƉŝůůĂƚƌĞƉŽƌƚŝŶŐƚŝŵĞ͘ ϭϬͬϯϬͬϮϬϮϭͲ^ĂƚƵƌĚĂǇ ŽŶƚ͘ƉƵŵƉŝŶŐΘƐƉŽƚƚŝŶŐEy^ůƵďĞĚŽǁŶĂƌŽƵŶĚĨŝƐŚ͘:ĂƌŽŶĨŝƐŚƐƚĂŐŝŶŐƵƉƚͬϱϬŬŽǀĞƌ͘ƵŵƉĚŽǁŶŽŶĨŝƐŚ͕ŶŽũŽǇ͘:ĂƌŽŶĨŝƐŚ ƐƚĂŐŝŶŐƵƉƚͬϲϬŬŽǀĞƌ͕ǁŝƚŚŶŽŵŽǀĞŵĞŶƚ͘WƵůůŝŶƚŽƚĞŶƐŝŽŶǁͬϲϬŬŽǀĞƌ͕ƉƵŵƉΛϯ͘ϯWD͕ϭ͕ϬϬϬƉƐŝ͕:ĂƌŽŶĨŝƐŚΛϲϬŬŽǀĞƌ͘ >ŝŶĞƵƉΘWƵŵƉƉĂƐƚĨŝƐŚΛϭďƉŵ͕ϭϭϬϬƉƐŝ͘ŽŶƚ͘ũĂƌƌŝŶŐŽŶĨŝƐŚΛϲϬŬŽǀĞƌƵŶƚŝůĨŝƐŚĐĂŵĞĨƌĞĞ͕WͬƵƚͬϭϬ͕ϱϱϵΖWhtсϭϮϳŬ͘ WƌĞĨŽƌŵĞĚƉŽƐƚũĂƌƌŝŶŐƌŝŐŝŶƐƉĞĐƚŝŽŶ͕ǁĞůůŽƵƚŽĨďĂůĂŶĐĞ͕ůĞƚƵͲƚƵďĞƚŚƌƵďůĞĞĚĞƌǁŚŝůĞŵŝǆϵ͘ϬƉƉŐĚƌǇũŽďƉŝůů͘WƵŵƉĞĚĚƌǇ ũŽďƉŝůů͕ǁĞůůƐƚĂƚŝĐ͕>ͬĚƐŝŶŐůĞĂŶĚZͬĚĐŝƌĐƵůĂƚŝŶŐĞƋ͘DͬƵƐŝŶŐůĞ͘WKK,ƐƚĂŶĚŝŶŐďĂĐŬϯͲϭͬϮΗǁŬ͘ƐƚƌŝŶŐƚͬ,͕ƐůŽǁƚƌŝƉĚƵĞƚŽ ŚŝŐŚǁŝŶĚƐ͘>ͬĚĂĐĐĞůĞƌĂƚŽƌũĂƌ͕ƐƚĂŶĚďĂĐŬΖƐ͕>ͬĚKŝůΘďƵŵƉĞƌũĂƌƐ͕ƉƵůůĞĚK^ĂŶĚĨŝƐŚĂďŽǀĞƌŝŐĨůŽŽƌ͕ƐŽĨĂƌƌĞĐŽǀĞƌŝŶŐϮ ƉƵŵƉƐ͕ĐĂďůĞĂŶĚĐůĂŵƉƐǁƌĂƉƉĞĚƵƉĂƌŽƵŶĚƐĞĐŽŶĚƉƵŵƉ͕ƌĞŵŽǀŝŶŐĐůĂŵƉƐĂŶĚĐĂďůĞ͘͘ WƵŵƉĞĚϭϯďďůƐŽĨ^ĂĨĞĐŝĚĚŽǁŶƚďŐ͕ĚŝƐƉůĂĐĞĚƚďŐǀŽůǁ ƉƵůůĞĚK^ĂŶĚĨŝƐŚĂďŽǀĞƌŝŐĨůŽŽƌ͕ƐŽĨĂƌƌĞĐŽǀĞƌŝŶŐϮ ƉƵŵƉƐ͕ĐĂďůĞĂŶĚĐůĂŵƉƐǁƌĂƉƉĞĚƵƉĂƌŽƵŶĚƐĞĐŽŶĚƉƵŵƉ͕ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ 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,<Ͳϭϭϭ͕ϰϭϵΖϭϭ͕ϰϱϳΖϵ͕ϮϯϴΖϵ͕ϮϲϴΖϯϬ͛ϱϬϲͬϮϲͬϮϬϭϰKƉĞŶ ,<Ͳϭϭϭ͕ϰϮϬΖϭϭ͕ϰϲϬΖϵ͕ϮϯϵΖϵ͕ϮϳϬΖϰϬΖKƉĞŶ ,<ͲϮϭϭ͕ϰϴϮΖϭϭ͕ϱϯϵΖϵ͕ϮϴϴΖϵ͕ϯϯϮΖϱϳ͛ϱϬϲͬϮϲͬϮϬϭϰKƉĞŶ ,<ͲϮϭϭ͕ϰϴϮΖϭϭ͕ϱϰϬΖϵ͕ϮϴϴΖϵ͕ϯϯϯΖϱϴΖKƉĞŶ ,<ͲϮϭϭ͕ϱϱϭΖϭϭ͕ϱϴϰΖϵ͕ϯϰϮΖϵ͕ϯϳϰΖϯϯ͛ϱϬϲͬϮϲͬϮϬϭϰKƉĞŶ ,<ͲϮϭϭ͕ϱϱϮΖϭϭ͕ϱϵϮΖϵ͕ϯϰϮΖϵ͕ϯϳϰΖϰϬΖKƉĞŶ ,<Ͳϯϭϭ͕ϱϵϮΖϭϭ͕ϲϱϱΖϵ͕ϯϳϰΖϵ͕ϰϮϯΖϲϯΖKƉĞŶ ,<Ͳϯϭϭ͕ϱϵϱΖϭϭ͕ϲϰϲ͛ϵ͕ϯϳϲΖϵ͕ϰϭϲΖϱϭ͛ϱϬϲͬϮϲͬϮϬϭϰKƉĞŶ ,<Ͳϰϭϭ͕ϲϱϱΖϭϭ͕ϳϳϰΖϵ͕ϰϮϯΖϵ͕ϱϭϳΖϭϭϵΖKƉĞŶ ,<Ͳϱϭϭ͕ϴϱϲΖϭϭ͕ϴϳϲΖϵ͕ϱϴϭΖϵ͕ϱϵϳΖϮϬΖ^ƋƵĞĞǌĞĚ ,<Ͳϲϭϭ͕ϵϮϬ͛ϭϭ͕ϵϳϱΖϵ͕ϲϯϭΖϵ͕ϲϳϰΖϱϱΖ/ƐŽůĂƚĞĚ :t>Zzd/> EŽ͘ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/ K/ƚĞŵ ϭϭ͕ϱϭϰ͛ϭ͕ϰϳϴ͛<ŝůů^ƚƌŝŶŐ;ϭϭͬϬϵͬϮϭͿ Ϯϭϭ͕ϴϬϬ͛ϵ͕ϱϯϳ͛/W &ŝƐŚ͗ ϭϭ͕ϲϳϲ͛ͲWĂƌƚŝĂůƌŝĚŐĞWůƵŐ ϭϭ͕ϲϴϴ͛ͲKďƐƚƌƵĐƚŝŽŶ ^WƌĞŵĂŝŶŝŶŐŝŶǁĞůůĂďŽǀĞ/W Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL 7%U K-17 (PTD 173-001) Punch 10/21/2021 Please include current contact information if different from above. 37' (6HW &KDQJHGGDWDWLWOHIURP058.WR7%8. $EE\%HOO Received By: 11/22/2021 By Abby Bell at 12:59 pm, Nov 22, 2021 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 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,120'11,676' Casing Collapse Structural Conductor Surface 1,540 psi Intermediate Production 4,230 psi 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: Katherine O'Connor 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 2,183' 12,096' Perforation Depth MD (ft): 12,096' 24" 13-3/8" 382'382' 2,183' 9,769'9-5/8" Length Size 12.6# / L-80 TVD Burst 9,677' 6,820 psi MD 3,090 psi 382' 2,038' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 173-001 50-733-20248-00-00 Trading Bay Unit K-17 McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools N/A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hilcorp Alaska, LLC Other: Install Kill String Bryan McLellan 11/8/2021 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: N/A & N/A N/A & N/A 10,828 - 11,774 8,793 - 9,517 In progress 4-1/2" 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dan Marlowe, Operations Manager Katherine.oconnor@hilcorp.com (907) 777-8376 9,787'11,800'9,537'2,420 psi 11,800' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:44 am, Nov 10, 2021 321-577 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.10 09:36:12 -09'00' Dan Marlowe (1267) DSR-11/10/21BJM 11/10/21 SFD 10-404 SFD 11/10/2021dts 11/12/2021 11/12/2021 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.12 08:31:29 -10'00' RBDMS HEW 11/15/2021 Well Work Plan Well: K-17 Date: 11/8/21 VER2 Well Name:K-17 API Number:50-733-20248-00 Current Status:ESP Producer Leg:Leg #1 NE Corner Estimated Start Date:Nov 8 2021 Rig:HAK 404 Reg. Approval Req’d? Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:173-001 First Call Engineer:Karson Kozub (907) 570-1801 (M) Second Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Current Bottom Hole Pressure:3,220 psi @ 8,016’ TVD 0.402 lbs/ft (7.73 ppg) from gauge on ESP Maximum Expected BHP:3,220 psi @ 8,016’ TVD 0.402 lbs/ft (7.73 ppg) from gauge on ESP Maximum Potential Surface Pressure: 2,420 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ** This is a No-Flow Well as of 12/20/15 Well Summary K-17 is a comingled G & Hemlock producer completed with an ESP that went to ground on March 6, 2021. This workover will replace the failed pump and clean out the well. The ESP was pulled and during the cleanout on K-17, the rig found a bad spot in the casing @ ±10740’ MD and drilled out of the casing. The rig subsequently pulled out of the hole with the workstring & bit. The objective is to run a kill string and leave the well full of KWF. The future utility of this well has not yet been determined. Last Casing Pressure Test: 06/24/2014 at 9,251’ to 1,500 psig for 30 minutes Procedure: 1. MIRU HAK Rig 404. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e- line and RIH to +/-9,650’ and punch tubing. Work over fluid will be FIW. BOP’s will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,000psi high/2,500psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP completion. 6. Contingent: RIH with cleanout assembly to ±11,700’, circulate well clean, POOH 7. PU and RIH with ±1500’ 4.5” kill string. 8. PU and RIH with new ESP completion. 9. Set BPV, NU tree, test same. 10. Turn well over to production. 11. Conduct SVS test per AOGCC regulations. 12. Conduct No-flow test per AOGCC regulations if cleanout is performed on step #6 13. Set BPV, NU tree, test same. 14. RD 404. 15. Leave well shut in. 16. Within 1 year, repair well or place downhole plug above perforations & damaged zone or prove the well is incapable of flowing on its own & has shown no signs of repressurization over the year. This Sundry was submitted as a change to the procedure on the approved sundry 321-118 - bjm r prove the well is incapable of flowing on its own & has shown no signs of repressurization over the year. Well Work Plan Well: K-17 Date: 11/8/21 VER2 Attachments: 1. Well Schematic Proposed 2. Wellhead Diagram Proposed 3. BOP Drawing 4. Fluid Flow Diagrams 5. RWO Sundry Revision Change Form Updated by: JLL 11/08/21 King Salmon Platform Well # K-17 PTD: 173-001 API: 50-733-20248-00 Completion: Future SCHEMATIC AS OF 11/8/2021 13 3/8” @ 2183’ Casing damage 7,816’ – 7,826’ Cement Sz’d 6/2014 9 5/8” csg G 1-6 CIBP @ 11,800’ MD HB-1,2,3,4 Hole in casing @ ±10,740 MD 24” @382’ Max HOLE ANGLE – 44° @ 3800’ TD = 12,120’ HB-5 - SQZD HB-6 KB = 100’ AMSL PBTD = 11,800’ 2 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24” 110 X52 Welded 23.124 Surface 382’ 13-3/8” 61 K-55 BTC 12.415 Surface 2,183’ 9-5/8”40.0 RS-95 BTC 8.835 Surface 7,031’ 43.5 RS-95 BTC 8.755 7,031’ 12,096’ TUBING DETAIL: Note: When pulling tubing – must pull singles PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Comment G-1 10,828' 10,846' 8,793' 8,806' 13 5 06/26/2014 Open G-2 10,878' 10,907' 8,830' 8,852' 22 5 06/26/2014 Open G-2 10,922' 10,946' 8,863' 8,881' 18 5 06/26/2014 Open G-3 10,990' 11,007' 8,913' 8,926' 13 5 06/26/2014 Open G-4 11,040' 11,086' 8,950' 8,984' 34 5 06/26/2014 Open G-4 11,127' 11,139' 9,015' 9,024' 9 5 06/26/2014 Open G-5 11,183' 11,249' 9,057' 9,107' 50 5 06/26/2014 Open G-6 11,318' 11,350' 9,160' 9,185' 25 5 06/26/2014 Open HK-1 11,419' 11,457' 9,238' 9,268' 30’ 5 06/26/2014 Open HK-1 11,420' 11,460' 9,239' 9,270' 40' Open HK-2 11,482' 11,539' 9,288' 9,332' 57’ 5 06/26/2014 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' Open HK-2 11,551' 11,584' 9,342' 9,374' 33’ 5 06/26/2014 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' Open HK-3 11,592' 11,655' 9,374' 9,423' 63' Open HK-3 11,595' 11,646’ 9,376' 9,416' 51’ 5 06/26/2014 Open HK-4 11,655' 11,774' 9,423' 9,517' 119' Open HK-5 11,856' 11,876' 9,581' 9,597' 20' Squeezed HK-6 11,920’ 11,975' 9,631' 9,674' 55' Isolated JEWELRY DETAIL No.Depth (MD) Depth (TVD)ID OD Item 2 11,800’ 9,537’ CIBP Fish: 11,676’ - Partial Bridge Plug 11,688’ - Obstruction ESP remaining in well above CIBP Updated by: JLL 11/08/21 King Salmon Platform Well # K-17 PTD: 173-001 API: 50-733-20248-00 Completion: Future PROPOSED 13 3/8” @ 2183’ Casing damage 7,816’ – 7,826’ Cement Sz’d 6/2014 9 5/8” csg G 1-6 CIBP @ 11,800’ MD HB-1,2,3,4 Hole in casing @ ±10,740 MD 24” @382’ Max HOLE ANGLE – 44° @ 3800’ TD = 12,120’ HB-5 - SQZD HB-6 KB = 100’ AMSL PBTD = 11,800’ 1 2 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24” 110 X52 Welded 23.124 Surface 382’ 13-3/8” 61 K-55 BTC 12.415 Surface 2,183’ 9-5/8”40.0 RS-95 BTC 8.835 Surface 7,031’ 43.5 RS-95 BTC 8.755 7,031’ 12,096’ TUBING DETAIL: 4-1/2” -- -- -- 3.958 Surf ±1,500’ Note: When pulling tubing – must pull singles PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Comment G-1 10,828' 10,846' 8,793' 8,806' 13 5 06/26/2014 Open G-2 10,878' 10,907' 8,830' 8,852' 22 5 06/26/2014 Open G-2 10,922' 10,946' 8,863' 8,881' 18 5 06/26/2014 Open G-3 10,990' 11,007' 8,913' 8,926' 13 5 06/26/2014 Open G-4 11,040' 11,086' 8,950' 8,984' 34 5 06/26/2014 Open G-4 11,127' 11,139' 9,015' 9,024' 9 5 06/26/2014 Open G-5 11,183' 11,249' 9,057' 9,107' 50 5 06/26/2014 Open G-6 11,318' 11,350' 9,160' 9,185' 25 5 06/26/2014 Open HK-1 11,419' 11,457' 9,238' 9,268' 30’ 5 06/26/2014 Open HK-1 11,420' 11,460' 9,239' 9,270' 40' Open HK-2 11,482' 11,539' 9,288' 9,332' 57’ 5 06/26/2014 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' Open HK-2 11,551' 11,584' 9,342' 9,374' 33’ 5 06/26/2014 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' Open HK-3 11,592' 11,655' 9,374' 9,423' 63' Open HK-3 11,595' 11,646’ 9,376' 9,416' 51’ 5 06/26/2014 Open HK-4 11,655' 11,774' 9,423' 9,517' 119' Open HK-5 11,856' 11,876' 9,581' 9,597' 20' Squeezed HK-6 11,920’ 11,975' 9,631' 9,674' 55' Isolated JEWELRY DETAIL No.Depth (MD) Depth (TVD)ID OD Item 1 ±1,500’ ±1,465’ Kill String 2 11,800’ 9,537’ CIBP Fish: 11,676’ - Partial Bridge Plug 11,688’ - Obstruction ESP remaining in well above CIBP King Salmon Platform K-17 Proposed 11/09/2021 24'’13 3/8'’ 9 5/8'’ Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim Starting head, FMC, 21 ¼ 2M X 24'’ SOW, w/ 1- 3 1/8 2M EFO All annular valves are 2 1/16 5M FMC 120Unihead, OCT type 3, 13 5/8 5M API hub top X 13 3/8 BTC casing bottom, w/ 1- 2 1/16 5M SSO on lower section, 1- 2 1/16 5M SSO on middle section, 3- 2 1/16 5M SSO on upper section , IP internal lockpin assy Adapter, FMC-A5P, 13 5/8 5M API clamp X 4 1/16 5M, w/ 7'’ extended neck pocket BHTA, Bowen, 4 1/16 5M FE x 7'’-5 Stub acme Bowen top King Salmon K-17 24 X 13 3/8 X 9 5/8 X 4 ½ Tbg hanger, OCT-UH-TC-1A- ESP, 13 X 4 ½ IBT lift and susp, w/ 4'’ Type H BPV profile 4 ½’’ King Salmon Platform BOP Stack HILCORP ALASKA, LLC SwacoSuperchokeBlooey LineTo Gas BusterInlet Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well K-17 (PTD 173-001)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 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 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,120'11,676' Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 4,230 psi Production 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:kkozub@hilcorp.com Contact Phone: (907) 570-1801 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 Authorized Signature: Operations Manager Karson Kozub PRESENT WELL CONDITION SUMMARY Length Trading Bay Unit K-17 COMMISSION USE ONLY Authorized Name: Size 11,800' TVD Burst 9,677' 6,820 psi Tubing Size: MD 3,090 psi 382' 2,038' 382' 2,183' 24" 13-3/8" 382' 2,183' Perforation Depth MD (ft): 10,828 - 11,774 12,096' N/A & N/A Tubing Grade:Tubing MD (ft): 8,793 - 9,517 Perforation Depth TVD (ft): 12.6# / L-80 Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 3/22/2021 4-1/2" Stan Golis for Dan Marlowe N/A & N/A 9,769'9-5/8"12,096' Other: Replace ESP N/A 9,787' 11,800' 9,537' 2,420 psi 173-001 50-733-20248-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:16 pm, Mar 08, 2021 321-118 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.03.08 14:58:15 -09'00' Stan Golis (880) BJM 3/15/21 10-404 SFD 3/9/2021 DSR-3/8/21 X BOP test to 3000 psi. Annular test 2500 psi. Comm. tion Required? Yes 3/16/21 dts 3/15/2021 JLC 3/15/2021 RBDMS HEW 3/17/2021 Well Work Plan Well: K-17 Date: 03/08/2021 Well Name:K-17 API Number:50-733-20248-00 Current Status:ESP Producer Leg:Leg #1 NE Corner Estimated Start Date:March 22, 2021 Rig:HAK 404 Reg. Approval Req’d? Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:173-001 First Call Engineer:Karson Kozub (907) 570-1801 (M) Second Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Current Bottom Hole Pressure:3,220 psi @ 8,016’ TVD 0.402 lbs/ft (7.73 ppg) from gauge on ESP Maximum Expected BHP:3,220 psi @ 8,016’ TVD 0.402 lbs/ft (7.73 ppg) from gauge on ESP Maximum Potential Surface Pressure: 2,420 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ** This is a No-Flow Well as of 12/20/15 Well Summary K-17 is a comingled G & Hemlock producer completed with an ESP that went to ground on March 6, 2021. This workover will replace the failed pump and clean out the well. Last Casing Pressure Test: 06/24/2014 at 9,251’ to 1,500 psig for 30 minutes Procedure: 1. MIRU HAK Rig 404. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e- line and RIH to +/-9,650’ and punch tubing. Work over fluid will be FIW. BOP’s will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,000psi high/2,500psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP completion. 6. Contingent: RIH with cleanout assembly to ±11,700’, circulate well clean, POOH 7. PU and RIH with new ESP completion. 8. Set BPV, NU tree, test same. 9. Turn well over to production. 10. Conduct SVS test per AOGCC regulations. 11. Conduct No-flow test per AOGCC regulations if cleanout is performed on step #6. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Diagram Current/ Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form 06/24/2014 at 9,251’ to 1,500 psig for 30 minutes Circulate wellbore volume with KWF again. BJM Less than 8 years since last MIT of production casing. OK. Updated by: JLL 07/29/19 King Salmon Platform Well # K-17 PTD: 173-001 API: 50-733-20248-00 Completion: 08/16/17 SCHEMATIC 13 3/8” @ 2183’ Casing damage 7,816’ – 7,826’ Cement Sz’d 6/2014 9 5/8” csg G 1-6 CIBP @ 11,800’ MD HB-1,2,3,4 Casing damage 9,098’ Cement Sz’d 6/2014 24” @382’ Max HOLE ANGLE – 44° @ 3800’ TD = 12,120’ HB-5 - SQZD HB-6 KB = 100’ AMSL PBTD =11,800’ 1 2 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24” 110 X52 Welded 23.124 Surface 382’ 13-3/8” 61 K-55 BTC 12.415 Surface 2,183’ 9-5/8”40.0 RS-95 BTC 8.835 Surface 7,031’ 43.5 RS-95 BTC 8.755 7,031’ 12,096’ TUBING DETAIL: 4-1/2” 12.6# L-80 IBT MOD 3.958 Surf 9,677’ Note: When pulling tubing – must pull singles PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Comment G-1 10,828' 10,846' 8,793' 8,806' 13 5 06/26/2014 Open G-2 10,878' 10,907' 8,830' 8,852' 22 5 06/26/2014 Open G-2 10,922' 10,946' 8,863' 8,881' 18 5 06/26/2014 Open G-3 10,990' 11,007' 8,913' 8,926' 13 5 06/26/2014 Open G-4 11,040' 11,086' 8,950' 8,984' 34 5 06/26/2014 Open G-4 11,127' 11,139' 9,015' 9,024' 9 5 06/26/2014 Open G-5 11,183' 11,249' 9,057' 9,107' 50 5 06/26/2014 Open G-6 11,318' 11,350' 9,160' 9,185' 25 5 06/26/2014 Open HK-1 11,419' 11,457' 9,238' 9,268' 30’ 5 06/26/2014 Open HK-1 11,420' 11,460' 9,239' 9,270' 40' Open HK-2 11,482' 11,539' 9,288' 9,332' 57’ 5 06/26/2014 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' Open HK-2 11,551' 11,584' 9,342' 9,374' 33’ 5 06/26/2014 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' Open HK-3 11,592' 11,655' 9,374' 9,423' 63' Open HK-3 11,595' 11,646’ 9,376' 9,416' 51’ 5 06/26/2014 Open HK-4 11,655' 11,774' 9,423' 9,517' 119' Open HK-5 11,856' 11,876' 9,581' 9,597' 20' Squeezed HK-6 11,920’ 11,975' 9,631' 9,674' 55' Isolated JEWELRY DETAIL No.Depth (MD) Depth (TVD)ID OD Item 33.75' 33.75’ FMC Hanger w/ 4” type H BPV profile 1 9,677’ 7,891’ - 5.13” Discharge, Bolt-On 9.677’ 7,891’ - 5.38” Pump (x3) 66 Stg SJ10000 9,748’ 7,949’ - 5.13” Intake/Gas Separator 9,750’ 7,951’ 5.13” Seals 513 Series BPBSL 9,768’ 7,965’ - 5.62” Motor(x2) 562 KMSUT 500 HP & 562 KMSLT 500 HP 9,830’ 8,016’ - 5.62” Gauge & Bullnose Anode 2 11,800’ 9,537’ CIBP Fish: 11,676’ - Partial Bridge Plug 11,688’ - Obstruction ESP remaining in well above CIBP Updated by: JLL 03/08/21 King Salmon Platform Well # K-17 PTD: 173-001 API: 50-733-20248-00 Completion: Future PROPOSED 13 3/8” @ 2183’ Casing damage 7,816’ – 7,826’ Cement Sz’d 6/2014 9 5/8” csg G 1-6 CIBP @ 11,800’ MD HB-1,2,3,4 Casing damage 9,098’ Cement Sz’d 6/2014 24” @382’ Max HOLE ANGLE – 44° @ 3800’ TD = 12,120’ HB-5 - SQZD HB-6 KB = 100’ AMSL PBTD =11,800’ 1 2 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24” 110 X52 Welded 23.124 Surface 382’ 13-3/8” 61 K-55 BTC 12.415 Surface 2,183’ 9-5/8”40.0 RS-95 BTC 8.835 Surface 7,031’ 43.5 RS-95 BTC 8.755 7,031’ 12,096’ TUBING DETAIL: 4-1/2” -- -- -- 3.958 Surf ±9,675’ Note: When pulling tubing – must pull singles PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Comment G-1 10,828' 10,846' 8,793' 8,806' 13 5 06/26/2014 Open G-2 10,878' 10,907' 8,830' 8,852' 22 5 06/26/2014 Open G-2 10,922' 10,946' 8,863' 8,881' 18 5 06/26/2014 Open G-3 10,990' 11,007' 8,913' 8,926' 13 5 06/26/2014 Open G-4 11,040' 11,086' 8,950' 8,984' 34 5 06/26/2014 Open G-4 11,127' 11,139' 9,015' 9,024' 9 5 06/26/2014 Open G-5 11,183' 11,249' 9,057' 9,107' 50 5 06/26/2014 Open G-6 11,318' 11,350' 9,160' 9,185' 25 5 06/26/2014 Open HK-1 11,419' 11,457' 9,238' 9,268' 30’ 5 06/26/2014 Open HK-1 11,420' 11,460' 9,239' 9,270' 40' Open HK-2 11,482' 11,539' 9,288' 9,332' 57’ 5 06/26/2014 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' Open HK-2 11,551' 11,584' 9,342' 9,374' 33’ 5 06/26/2014 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' Open HK-3 11,592' 11,655' 9,374' 9,423' 63' Open HK-3 11,595' 11,646’ 9,376' 9,416' 51’ 5 06/26/2014 Open HK-4 11,655' 11,774' 9,423' 9,517' 119' Open HK-5 11,856' 11,876' 9,581' 9,597' 20' Squeezed HK-6 11,920’ 11,975' 9,631' 9,674' 55' Isolated JEWELRY DETAIL No.Depth (MD) Depth (TVD)ID OD Item 33.75' 33.75’ FMC Hanger w/ 4” type H BPV profile 1 ±9,675’ ±7,890’ - - Discharge, Bolt-On --Pumps - - Intake/Gas Separator -Seals - - Motor ±9,830’ ±8,015’ - - Gauge & Bullnose Anode 2 11,800’ 9,537’ CIBP Fish: 11,676’ - Partial Bridge Plug 11,688’ - Obstruction ESP remaining in well above CIBP King Salmon Platform K-17 King Salmon Platform BOP Stack Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) CPumpManifold3(PM3) OPumpManifold4(PM4) CPumpManifold5(PM5) OMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) OPumpManifold3(PM3) CPumpManifold4(PM4) OPumpManifold5(PM5) CMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. x Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1 st valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1st valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve / open outside valve on kill side of mud cross, close valves 5 & 6 / open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to ~ 1200 psi and bleed off 200 – 300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record “Accumulator Pressure”. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read “10 bottles at 2,150 psi”). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to “Auto”, not “Manual” so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well K-17 (PTD 173-001)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKA AL OIL AND GAS CONSERVATION COMIXION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown El Performed: Suspend El Perforate ❑ Other Stimulate pi/ Alter Casing CIChange Approved Program ElPlug for Redrill ❑ Perforate New Pool ❑ Repair Well Re-enter Susp Well❑ Other:Replace ESP 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 173-001 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20248-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit K-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,120 feet Plugs measured 11,800 tE C E I V E C true vertical 9,787 feet Junk measured 11,676 feet �e• SEP 1 3 2017 Effective Depth measured 11,800 feet Packer measured N/A feet true vertical 9,537 feet true vertical N/A feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,038' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner Perforation depth Measured depth 10,828 11,774 feetSIMON '`t,i i True Vertical depth 8,793-9,517 feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 9,677'(MD) 7,891'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 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: 0 0 0 420 419 Subsequent to operation: 107 141 6341 88 99 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPLO Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ 3USP❑ SPLUGO 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: 317-201 Authorized Name: Stan W.Golis Contact Name: Joe Kaiser Authorized Title: Operations Manager Contact Email:lkaiserthilcorp.com Authorized Signature: 'w••••• W Date: 1 ( " ( %1 Contact Phone: (907)777-8393 /r ic:/x RDD AS t ti SEP 2 5 2017 Form 10-404 Revised 4/2017 Submit Original Only /(//.-- -'--7 . King Salmon Platform • 14 • Well#K-17 SCHEMATIC PTD: 173-001 API: 50-733-20248-00 Hilt orp Ahneku,Lilt Completion:08/16/17 KB=100'AMS1, CASING DETAIL SI2E WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 40.0 RS-95 BTC 8.835 Surf 7,031' 1338"@2183' 9-5/8" 43.5 RS 95 BTC 8.755 7,031' 12,096' ah FL TUBING DETAIL: 4-1/2" 12.6# L-80 IBT MOD 3.958 Surf 9,677' Note: When pulling tubing-must pull singles Casing cbr age ` 7,816'-7,826' ' + CerrertS&d612314 JEWELRY DETAIL Depth Depth No. ID OD (MD) (TVD) Item Casing damage 33.75' 33.75' FMC Hanger w/4"type H BPV profile " 9,677' 7,891' - 5.13" Discharge,Bolt-On CaretSd6'2014 9.677' 7,891' - 5.38" Pump(x3)66 Stg SJ10000 1 9,748' 7,949' - 5.13" Intake/Gas Separator 9,750' 7,951' 5.13" Seals 513 Series BPBSL 9,768' 7,965' - 5.62" Motor(x2)562 KMSUT 500 HP&562 KMSLT 500 HP "" 9,830' 8,016' - 5.62" Gauge&Bullnose Anode 2 11,800' 9,537' CIBP 1 L PERFORATION DATA Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Feet SPF Date Comment G-1 10,828' 10,846' 8,793' 8,806' 13 5 06/26/2014 Open G16G-2 10,878' 10,907' 8,830' 8,852' 22 5 06/26/2014 Open G-2 10,922' 10,946' 8,863' 8,881' 18 5 06/26/2014 Open G-3 10,990' 11,007' 8,913' 8,926' 13 5 06/26/2014 Open = HB-1,2,3,4 G-4 11,040' 11,086' 8,950' 8,984' 34 5 06/26/2014 Open G-4 11,127' 11,139' 9,015' 9,024' 9 5 06/26/2014 Open G-5 11,183' 11,249' 9,057' 9,107' 50 5 06/26/2014 Open G-6 11,318' 11,350' 9,160' 9,185' 25 5 06/26/2014 Open 2 °BP@II'&10'ND HK-1 11,419' 11,457' 9,238' 9,268' 30' 5 06/26/2014 Open : HB-5-SQZD HK-1 11,420' 11,460' 9,239' 9,270' 40' Open HK-2 11,482' 11,539' 9,288' 9,332' 57' 5 06/26/2014 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' Open I HK-2 11,551' 11,584' 9,342' 9,374' 33' 5 06/26/2014 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' Open 11f3C HK-3 11,592' 11,655' 9,374' 9,423' 63' Open HK-3 11,595' 11,646' 9,376' 9,416' 51' 5 06/26/2014 Open .F-• a , , HK-4 11,655' 11,774' 9,423' 9,517' 119' Open yr . ;,4 ,,, -':;';,-'‘i:::1:4-.,-::'4; : ' ` HK-5 11,856' 11,876' 9,581' 9,597' 20' Squeezed ,,., '�; .'"t',} HK-6 11,920' 11,975' 9,631' 9,674' 55' Isolated .:°` ' r `"a"\ 9 5'8' csg PBTD=11,a T ID=12,12D Fish: NlzaHCLEANGLE-44°@380p' 11,676'-Partial Bridge Plug 11,688'-Obstruction ESP remaining in well above CIBP Updated by:JLL 09/08/17 • • 1111 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-17 Moncla 404 50-733-20248-00 173-001 8/10/17 8/16/17 Dai,(y;Operations e 08/10/2017-Thursday Continue spotting equipment, double beam racking mat, double beam, single beam, spreader bars carrier, rig pump, rig tank, power swivel. C/O 4 sheave bearings in crown cluster w/ rig Mech. Power wash rig as we go. RU rig tank to mud pump. Rigged mud pump to K-17 tubing. Rigged K-17 casing valve to production returns. Bolted down draw works to carrier. Connected brake linkage and control console. Spotted racking mat extension beam, tack weld to racking mat beam. Secured carrier stabilizer cables. Circulate well down tubing with FIW at 2.0 BPM taking returns via casing valve, all returns shipped to Trading Bay (NPFT submitted, approved and copy saved to 0 drive). NOS rep test hanger void and neck seals-5000 psi - GOOD TEST. Welder finishes derrick modifications. Continue circulate well with FIW at 2.0 BPM. Mount A-frame and derrick on carrier. Install K-3 valve, mounted driller console, set drill shack, spotted test pump and bang box. Finish circulating well with FIW at 2.0 BPM. Pumped total of 780 BBL FIW, shut down and observe well for flow. Half-mast derrick. String drill line, cat lines and cables. IA= 200 psi, Tubing= 0 psi. Line up to choke manifold and attempt to bleed IA down. Lay down derrick. 08/11/2017- Friday IA= 100 psi, Tubing= 0 psi. Line up to choke manifold and attempt to bleed IA down. Circ down tubing W/ FIW @ 1.3/4 BBL min W/0 on tubing. Take returns through choke manifold W/60 PSI on back side. Attempt to clean up oil on back side. Pump 400 bbls W/shut down and pump out oil rig tank t/ production. Monitor well 15 mins ok. Tubing press 0 and Ann press 75 PSI. R/D Hose and Set BPV and N/D Tree and N/U BOP. Finish N/D Tree. N/U BOPE stack.Tack weld racking mat extension beam to racking mat beam. Install 2-7/8" X 5" VBRs in dual gate BOP. Stand up, scope out derrick. Secure guide wires. Work M/V Titan -offload Summit spoolers, spools and connex. Spot and secure drillers shack, mount stairs on driller shack side of carrier. Continue to tighten unit-bolt head clamp to spec. Mount rig floor. MU choke and koomey lines to BOPE stack. RU test pump. Ran air and electric lines to koomey. MU kill line to K3 valve. MU pump line and kill line to circulating manifold. Continue to tighten BOP stack flange bolts/nuts to spec. MU 4-1/2" test joint and ported sub. Spot tong power pack on racking mat. Clean and clear around rig. Prep for BOPE test. 08/12/2017 -Saturday Cont'd R/U floor remodify legs on rig floor platform w/welder and r/u rig floor tools, power tong, slips, elevators, f/4 1/2" equipment. Rig up Test Equip and pre test 250/2500 All good. R/U ESP spools w/summit hands.Test BOP 250 lower f/5 mins/ High 2500 f/5 mins. AOGCC witness is waived by E-Mail,Jim Regg on K-17. LD test joint and ported sub. Pull BPV. MU landing joint with pump-in sub, safety valve and IBOP. Circulate well to tubing with FIW at 2.80 BPM, 200 psi, taking returns at casing valve. Sending all returns to Trading Bay (NPFT completed, submitted and approved. Copy saved to 0-drive well files). Increase pump rate to 3.30 BPM, 688 psi, solid oil returns. Stop circulating well -930 BBL FIW total volume-well on vacuum. LD pump-in sub and !BOP. NOS rep BO lock down screws. Pull tubing hanger to rig floor, PUW= 154K. Summit reps disconnecting control lines and power cable from tubing hanger and Pull 3 stands. R/U cables through sheaves. • • • 111 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-17 Moncla 404 50-733-20248-00 173-001 8/10/17 8/16/17 Daily Operations: 08/13/2017-Sunday Summit reps disconnecting control lines and power cable from tubing hanger and Pull 3 stands. R/U cables through sheaves. Cont'd POOH and stand back in derrick 4 1/2" 12.6# L-80 IBT MOD and spool up ESP cables as go. Pump 15 BBL FIW every 10 stands. 129 stands in the derrick (2,468'). Discussed procedure for recovery of parted ESP assy during tour change PJSM. Finished POOH w/ ESP assy from 2,468' standing back 4-1/2", 12.6# L-80 IBT MOD tubing in derrick. Pump 15 BBL FIW every 10 stands. 168 stands in derrick. BD ESP assy- leads burnt off bottom of upper tandem motor- brass in oil - lower tandem motor checked grounded. Pump 20 BBL FIW every hour on the hour. Clear and clean rig floor- prep for ESP assy install. Load hole with 101 BBL FIW. Summit swaps out used power cable and flat pack spools and loads new power cable and flat pack spools in spoolers for ESP assy completion install. PJSM with Summit to discuss procedures for making up ESP assy. MU ESP Assy. MU dual tandem 500 HP motors and gauge, fill dual tandem motors with oil. Pump 20 BBL FIW every hour on the hour. 08/14/2017-Monday PJSM with Summit to discuss procedures for making up ESP assy. MU ESP Assy. MU dual tandem 500 HP motors and gauge, fill dual tandem motors with oil. MU pumps 66 stage, SJ10000 and discharge bolt-on, ported press sub, xo,4 1/2" 12.6# BTC mod jt. Pump 20 BBL FIW every hour on the hour.Test ESP cable every 1000'. RIH W/ ESP Assembly W/summit on 4 1/2" 12.6# BTC mod to 3,740' (60 stands).Test ESP cable every 1000'. Drift pipe out of derrick as go. Pump 15 BBL every 10 stands. Continue TIH with Summit dual tandem 500 HP motors ESP assy on 4-1/2" 12.6# L- 80 IBTC MOD tubing from 3,740'to 5,029' (85 stands).Test insulation every 1000'. Drift pipe out of derrick. Pump 15 BBL FIW every 10 stands. Summit reps splicing power cable. Pump 15 BBL FIW every hour on the hour. Continue TIH with Summit dual tandem 500 HP motors ESP assy on 4-1/2" 12.6# L-80 IBTC MOD tubing from 5,029' to 8009'. Test insulation every 1000'. Drift pipe out of derrick. Pump 15 BBL FIW every 10 stands. 08/15/2017-Tuesday Continue TIH with Summit dual tandem 500 HP motors ESP assy on 4-1/2" 12.6# L-80 IBTC MOD tubing T/9,799'. Test insulation every 1000'. Drift pipe out of derrick. Pump 15 BBL FIW every 10 stands. M/U FMC 13 5/8" hanger prepped w/ ESP penetrator w/control lines. Splice W/ ESP cable through hanger and hook up flat pack cable through hanger.Test cables, lower hanger in place, RILDS.Test ESP cables. All good.TD 4-1/2" 12.6# L-80 IBTC MOD ESP completion assembly at 9,834.58'. R/D Summit Equip cables/sheaves f/derrick. Back out landing jt and lay down same. Set BPV. R/D Rig floor platform tools power tongs. R/D Derrick and scope down and lay over. R/D BOPE stack. Pressure wash rig floor, McCoy tongs, mud cross and riser. N/U tree and flow lines. RD Quadco monitor equipment, rig pump, koomey lines and choke lines. BD circulation manifold. Roll up air and electric lines, clean rig tank. Working M/V Resolution - back loading Summit spools, spoolers, connex, ESP motors, un-used 4-1/2" tubing and trash dumpster. Continue to RD. Clean and prep rig for rig move.Test tubing hanger head void = 500 psi(5 mins)/5000 psi(15 mins). Hook up flow lines.Turn over t/ production. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-17 Moncla 404 50-733-20248-00 173-001 8/10/17 8/16/17 Daily Operations: 08/16/2017-Wednesday Continue R/D Moncla 404 Rig. Clean up and rig. Service mud pump, pony rod seals. Clean up BOP Stack. Scrub deck. Clean up all rig hoses and cables. Clean and clear rig equipment and drill deck prepping for rig move. Working M/V Resolution - back loading loads for delivery to Grayling Platform. M/V Resolution leaves King Salmon delivering load to Grayling Platform. M/V Resolution returns empty, work boat back loading derrick and A-frame, carrier, draw works, rig beams, drillers shack, walkways, stairs, landings and connexes for delivery to Grayling Platform. M/V Resolution leaves King Salmon delivering load to Grayling Platform. Continue to clean and clear rig equipment and drill deck prepping for rig move to Grayling Platform.,Fly rig crews to Grayling Platform. Last report for Well K-17. • • t4 v-17 Pft 1/36610 Regg, James B (DOA) From: Ronnie Dalton - (C) <rdalton@hilcorp.com> a' Sent: Sunday, August 13, 2017 8:27 AM �� '�1 `°I 16W7 To: Regg, James B (DOA) Cc: Joe Kaiser; Dan Marlowe Subject: Rig 404 BOP test Attachments: Test charts.pdf; BOP TEST 8-12-17.xlsx; Moncla 404 BOPE Test Procedue2.docx Jim, As per our discussion on the phone, I have made an honest mistake on our BOP test. I was looking at the wrong sundry and tested below the 3500 I was supposed to test to. Here are my test charts along with the configuration on how we tested them. I can do anything you would like me to do, at any given time, to correct my mistake. Thank you sir I r . Hilcorp Alaska, LLC DSM King Salmon SCANNED `-F , 2 52300 Nikiski Beach Rd. Nikiski, AK 99635 Work: (907) 776-6699 Cell: 828-447-5555 11 ffilourpr lhcuk1.1,11 1 • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *AII BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regqaalaska.gov;AOGCC.Inspectorsaa.alaska.gov; phoebe.brooks a(�,alaska.gov Contractor: Moncla Rig No.: 404 DATE: 8/12/17 - Rig Rep.: J Freeman Rig Phone: 907-776-6698 Operator: Hilcorp Alaska Op. Phone: 907-776-6699 VRep.: Ronnie Dalton E-Mail rdalton@hilcorp.com Well Name: I' (� �C_1 PTD# 173.90'fD Sundry# 317.261' 3/7- Z( (*-4°' (1300(o 4"T. Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250-2500 - Annular: 250-2500 - Valves: 250-2500 - MASP: 2709 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P _ Well Sign P Upper Kelly 0 NA Housekeeping P - Rig P Lower Kelly 0 NA PTD On Location P - Hazard Sec. P , Ball Type 1 - P - Standing Order Posted P Misc. NA Inside BOP 1 - P - FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13 5/8"5M P - Pit Level Indicators P P - #1 Rams 1 2 7/8"x 5"VBR P - Flow Indicator NA NA #2 Rams 1 Blind P - Meth Gas Detector P - P #3 Rams 0 NA H2S Gas Detector P • P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 2 1/16" P - Inside Reel valves 0 NA HCR Valves 2 2 1/16" P Kill Line Valves 1 2 1/16" P - Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 - P CHOKE MANIFOLD: Pressure After Closure(psi) 1900 - P - Quantity Test Result 200 psi Attained(sec) 32 - P - No.Valves 10 - P - Full Pressure Attained(sec) 156 • P Manual Chokes 1 - P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 - P - Nitgn. Bottles#&psi(Avg.): 6@2000 - P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 4.0 Hours Repair or replacement of equipment will be made within N/A days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested with 4 1/2"test Jt only. 5(441 l G '3co t k— / apts if Vlwie-5 D1161/7 AOGCC Inspection 24 hr Notice Yes Date/Time 8/11/17 9:00 AM Waived By Jim Regg Test Start Date/Time: 8/12/2017 14:00:00 PM (date) (time) Witness Test Finish Date/Time: 8/12/2017 18:00:00 PM Form 10-424(Revised 03/2017) BOP TEST 8-12-17 • • Moncla 404 BOPE Test Procedure 1. Fill stack w/ FIW through kill line with all K, C and M valves open except M2 & M10. 2. Close M1 when choke manifold is full- shutdown pump when stack is full- close K3 and annular 3. Fill test jt w/ test pump till fluid comes out IBOP- close IBOP. `Tes4- ss sti,,,Le( be 35OD ,' it c itA �J Test #1 With Annular, Ml, M2, M10, K3 & IBOP closed- pressure up to 250#s- hold f/ 5 mins. Pressure up to 2500 and hold for 5 mins. Release pressure. Test #2 Close pipe rams and open annular, close Safety Valve- open IBOP, close - open K3, close M3 & M4- open Ml, close M9- open M2. Test low & high f/ 5 mins. Release pressure. Test #3 Close Kl- open K2, close M5 & M6- open M3 & M4. Test low & high f/ 5 mins. Release pressure. Test #4 Close manual & super chok(- open M5 & M6. Pressure up to 1200#s & bleed down 200- 300#s w/ each. Release pressure. Test #5 Close C2 (HCR)- open manual & super choke. Test low & high f/ 5 mins. Release pressure. Test #6 Close Cl- open C2 (HCR). Test low 250 & high 2500 f/ 5 mins. Release pressure. Test #7 Perform accumulator drawdown test: 1) Turn off electric & air pumps 2) Record accumulator pressure (+- 3000 PSI) 3) Close annular, pipe rams & HCR- open pipe rams to simulate blinds 4) While pressure is stabilizing check pressures in nitrogen bottles & record 5) Record accumulator pressure 6) Turn on electric pump & time seconds to pressure up 200 psi- turn on air pumps & time till unit pressures up to 3000 psi & shuts off (time will start from time electric pump starts till all pumps shut off). Test #8 Pull test jt and close blinds. Move test line to M10- close M7 & M8- open M10. Test low & high f/ 5 mins. Release pressure. Test additional pipe sizes and safety valves as needed S . �ciN. . 4�04— • 7311-- le—( 7 w is __ ,. 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NN, --. ___ - -------=----- •- ----7- _-- •••_,,,,--<: __,- 2./ /., ,/////zit \ \\,. -,,,, •,,,,,,. ---4:-7----_________ 7--- . - 1\\ , ,, f ^z---- ----- ..- .,,, . .//// •/'/ // \ \\ \<-\,,,,,•-„,...._".•-, ,,,....1. ----,..,______ __,...... -___. _ ________.....„.„---________-__>,_ v///// \N ---17------- --__ 0002 .sl;'<.--,7'''''',,,,,,,---..„_„,„,,..:------..,,,T---":„::::---.---...7....1..l.f- _____°°_°17_-_----7. -----i_.r-----'--_._____,, --,:„...<----:,...1:_, c:7 J.--- i Op 1_ ---------- ---- 11 VOF T4� • • w..,\ y,�s� THE STATE Alaska Oil and Gas N — 14 of e TT /� T� //�� Conservation Commission Vrit; . AL1Z��`1Z rl ,#: �� x 333 West Seventh Avenue ' ,� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFA- S.Q. Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis smit MA' 2 a ri.0 :'. Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-17 Permit to Drill Number: 173-001 Sundry Number: 317-201 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, I. I P 20,,,c4, Cathy 1. Foerster Chair DATED this ID day of May,2017. RBDMS LL, MAY 1 8 2017 • • RECEIVED • MAY 157017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION A CC APPLICATION FOR SUNDRY APPROVALS '� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing D Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Replace ESP 2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development [j , 173-001 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-733-20248-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No El I Trading Bay Unit K-17 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 , McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ' 12,120 9,787 ' 11,800 • •9,537 2,709 psi 11,800 11,676 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,038' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,828-11,774 . 8,793-9,517 4-1/2" 12.6#/L-80 9,680 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary El Wellbore schematic Ej 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: Commencing Operations: 7/25/2017 OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe©hilcorp.com � ^^ s7' ZD{1 S Contact Phone: (907)283-1329 Authorized Signature: w 64Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number _ k1- 2o Plug Integrity ❑ BOP Testi Mechanicalt.r ,S Integrity Test ❑ Location Clearance ❑ F.. 11 o •C �1 Other: 3 50 C1 r 5 L 66 tr7;7;1-- Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Li Subsequent Form Required: lb- LI ail RBDMS Lv l',.,,i 1 8 2017 APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: SP—.., l 0 -/7 11(.54 ,f4/4/7 S—/7I7 Submit Form and Form 10-403 Revised 4/2017 0 ,R` { v� p Ifirafl valid for 12 months from the date of approval. Attachments in Duplicate • • Well Work Plan Well: K-17 Hilcorp Alaska,LL Date:05/03/2017 Well Name: K-17 API Number: 50-733-20248-00 Current Status: ESP Lifted Producer Leg: Leg#1 NE Corner Estimated Start Date: July 25, 2017 Rig: Moncla 404 Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 173-001 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 Current Bottom Hole Pressure: 3,588 psi @ 8,793'TVD 0.408 lbs/ft(7.85 ppg)from gauge on ESP Maximum Expected BHP: 3,588 psi @ 8,793'TVD 0.408 lbs/ft(7.85 ppg)from gauge on ESP Maximum Potential Surface Pressure:2,709 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) **This is a No-Flow Well as of 08/22/15 Well Summary j K-17 is a comingled G & Hemlock producer completed with an ESP that failed March 23, 2017. This workover will replace the failed pump. / Last Casing Pressure Test: 06/05/2014 at 7,816'to 1,500 psig for 30 minutes Procedure: 1. MIRU Moncla Rig 404. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e- line and RIH to+/-9,800'and punch tubing.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). c nti..1..w. ft 2--"5-61'7 p. ` ) 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP completion. 6. PU and RIH with new ESP completion. 7. Set BPV, NU tree,test same. 8. Turn well over to production. 9. Conduct SVS test per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Diagram Current/Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • • King Salmon Platform Well#K-17 SCHEMATIC PTD: 173-001 API:50-733-20248-00 H'icorp Alaska,1.1,C Completion: 12/07/2015 KB=100'ANBL CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 40.0 RS-95 BTC 8.835 Surf 7,031' 1.33/8”@2183' 9-5/8" 43,5 RS-95 BTC 8.755 7,031' 12,096' TUBING DETAIL: dal 4-1/2" 12.6# L-80 IBT MOD 3.958 Surf 9,680' Note: When pulling tubing-must pull singles Casing defray r 7,816'-7,625 iv CerrertSid 62Q1a JEWELRY DETAIL Depth Depth No. ID OD (MD) (TVD) Item Casing darrage 33.7' 33.7 FMC Hanger w/4"type H BPV profile CerriatSid 6n014 1 9,680' 7,893' 6.750" Discharge,Bolt-On 2 9,681' 7,894' - 6.750" Pump Summit 90 stage SH12000 1 3 9,725' 7,930' - 6.750" Intake 5.130" Seals 2 4 9,744' 7,946' - 5.620" Motor Schlumberger 1153 HP 562 Series(Used) 1" 5 9,815' 8,004' - 5.620" Centralizer/Anode/Used XT-150 Gauge 36 11,800' 9,537' CIBP Art 4 5 4 PERFORATION DATA Zone Top Btm Top Btm Feet SPF Date Comment (MD) (MD) (TVD) (TVD) G-1 10,828' 10,846' 8,793' 8,806' 13 5 06/26/2014 Open G1-6G-2 10,878' 10,907' 8,830' 8,852' 22 5 06/26/2014 Open G-2 10,922' 10,946' 8,863' 8,881' 18 5 06/26/2014 Open G-3 10,990' 11,007' 8,913' 8,926' 13 5 06/26/2014 Open .: HB'-1,2,3,4 G-4 11,040' 11,086' 8,950' 8,984' 34 5 06/26/2014 Open G-4 11,127' 11,139' 9,015' 9,024' 9 5 06/26/2014 Open 4 - G-5 11,183' 11,249' 9,057' 9,107' 50 5 06/26/2014 Open QG-6 11,318' 11,350' 9,160' 9,185' 25 5 06/26/2014 Open 6 QBP@11,8130'NDHK-1 11,419' 11,457' 9,238' 9,268' 30' 5 06/26/2014 Open : HB-5-KM HK-1 11,420' 11,460' 9,239' 9,270' 40' Open HK-2 11,482' 11,539' 9,288' 9,332' 57' 5 06/26/2014 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' Open e ..?:El HK-2 11,551' 11,584' 9,342' 9,374' 33' 5 06/26/2014 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' Open HB-6 HK-3 11,592' 11,655' 9,374' 9,423' 63' Open HK-3 11,595' 11,646' 9,376' 9,416' 51' 5 06/26/2014 Open - . ,r. ,,,,* r4 HK-4 11,655' 11,774' 9,423' 9,517' 119' Open i r'y*p4:4 HK-5 11,856' 11,876' 9,581' 9,597' 20' Squeezed r+: 1 Vc ; HK-6 11,920' 11,975' 9,631' 9,674' 55' Isolated ,a �'�;,lt , 958"csg PB1D=11,800 TD=12,120 Fish: MEXHOLE PNaE-44 @3830' 11,676'-Partial Bridge Plug 11,688'-Obstruction ESP remaining in well above CIBP Updated by:1LL 12/11/15 • • King Salmon Platform Well#K-17 11 PROPOSED PTD: 173-001 API:50-733-20248-00 Hilcorp Alaska,Ll.f. Completion: FUTURE KB=100'AIVEL CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. .:. 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9 5/8" 40.0 R5-95 BTC 8.835 Surf 7,031' 133V @2183 43.5 RS-95 BTC 8.755 7,031' 12,096' TUBING DETAIL: 4-1/2" 12.6# L-80 IBT MOD 3.958 Surf ±9,680' Note: When pulling tubing-must pull singles i Casing danPge II 7,816-7,826' Carait SYd 62014 JEWELRY DETAIL Depth Depth No. ID OD (MD) (TVD) Item Casis "9 ' 33.7' 33.7' FMC Hanger w/4"type H BPV profile 14 Cement Szd62014 - 6.750" Discharge,Bolt-On - 6.750" Pump mow_ 1 - 6.750" Intake 5.130" Seals 5.620" Motor iju ±9,815' ±8,004' - 5.620" Centralizer/Anode III 6 11,800' 9,537' CIBP Anti lir- 1 r PERFORATION DATA Zone Top Btm Top Btm Feet SPF Date Comment (MD) (MD) (ND) (ND) G-1 10,828' 10,846' 8,793' 8,806' 13 5 06/26/2014 Open G1-65 10,878' 10,907' 8,830' 8,852' 22 5 06/26/2014 Open G-2 10,922' 10,946' 8,863' 8,881' 18 5 06/26/2014 Open G-3 10,990' 11,007' 8,913' 8,926' 13 5 06/26/2014 Open C 113-1,2,3 4 G-4 11,040' 11,086' 8,950' 8,984' 34 5 06/26/2014 Open G-4 11,127' 11,139' 9,015' 9,024' 9 5 06/26/2014 Open - G-5 11,183' 11,249' 9,057' 9,107' 50 5 06/26/2014 Open Q'1 G-6 11,318' 11,350' 9,160' 9,185' 25 5 06/26/2014 Open 6 (rw@lifficrNE' HK-1 11,419' 11,457' 9,238' 9,268' 30' 5 06/26/2014 Open igi . HB-5- HK-1 11,420' 11,460' 9,239' 9,270' 40' Open HK-2 11,482' 11,539' 9,288' 9,332' 57' 5 06/26/2014 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' Open 21 ? HK-2 11,551' 11,584' 9,342' 9,374' 33' 5 06/26/2014 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' Open 1� HK-3 11,592' 11,655' 9,374' 9,423' 63' Open HK-3 11,595' 11,646' 9,376' 9,416' 51' 5 06/26/2014 Open 't' HK-4 11,655' 11,774' 9,423' 9,517' 119' Open HK-5 11,856' 11,876' 9,581' 9,597' 20' Squeezed i ^ HK-6 11,920' 11,975' 9,631' 9,674' 55' Isolated , 1 "'Ets �� ,i !''T� 958"c"b PBTD=11,80G TD=12,120' Fish: Max HCLEANGLE-44°@38017 11,676' - Partial Bridge Plug 11,688'-Obstruction ESP remaining in well above CIBP Updated by:ILL 05/11/17 • • King Salmon Platform K-17 HiIrnrp Alaska,LI.i: King Salmon Tbg hanger,OCT-UH-TC-1A- K-17 ESP,13 X 4%IBT lift and 24 X 13 3/8 X 9 5/8 X 4% susp,w/4"Type H BPV profile,3/8 cont control line port BHTA,Bowen,4 1/16 5M FE x 7"-5 Stub acme Bowen top 1 0 0 Jul m...m tnt Valve,Swab,WKM-M,4 1/16 5M FE,HWO,EE trim alt , �c Valve,Wing,SSV,WKM-M,3 1/8 5M 0.0 v FE,w/OMNI oper,EE trim nn tm Valve,Wing,WKM-M,2 1/16 5M FE,HWO,DD trimN /IT N li J 11111 4ac 1\1 i. a.a Luis 11.11\1 Valve,Master,WKM-M,4 1/16 5M u u�^ IC /p FIR1.1 • FE,HWO,EE trim �H✓ u �tei 41i(I I.I1.i.l.l i.i e MNMNIIIII Mt lil Ii1 i61 Valve,Wing,WKM-M,3 1/8 5M FE, #" HWO,EE trim Ill all& • _,„,,I-IIA Adapter,OCT-AS-ESP,13 5/8 5M API hub iir_i___ 7 X 4 1/16 5M stdd top,w/2-%:control MI 11 line exits,prepped w/OCT 400-4 pocket I II ,P.o.'- 1414 i ts_.:").il-I II 7,71 ,.PEN p.,„ rj _ All unihead annular valves,2 Unihead,OCT type 3,13 5/8 5M API ® 17 • '2 1/16 5M FE OCT-20,HWO hub top X 13 3/8 BTC casing bottom, i• = r +4r�• + - 1 I" w/1-2 1/16 5M SSO on lower — 111 , • I • section,1-2 1/16 5M SSO on middle ELr ^ .1 section,3-2 1/16 5M SSO on upper ' a section,IP internal lockpin asst' —a = 1 (-1VI'" 1 16' 1 ', Valve,OCT-20,3 1/8 2M FE, IiiStarting head,OCT,21 Y.2M FE X – 1 da—"11113 ,>l_ ! _S HWO 24"SOW,w/1-3 1/8 2M EFO,full I'l.o•..0,I set of lockpins I _ I I .I 24', 1 13 3/8" n 9 5/8" X- 4 Y2,, • 0 King Salmon Platform , ll BOP Stack(Moncla) Bilcoga:SII,'.'. . 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D 0 CC 0 • • 111 Moncla Rig 404 BOP Test Procedure Haror,,I,,ka,r.u; Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) Moncla Rig 404 BOP Test Procedure Hil�r�Alaska,LLC Attachment#1 �� f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close ft valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross,open ft valve of standpipe, close valves 3,4&9 on choke manifold, open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross, close valves 5&6/open valves 3 &4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to 1200 psi and bleed off 200—300 Us recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross), open manual &super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • • Moncla Rig 404 BOP Test Procedure Rilcorp Alaska,L1.( Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • 0 a) ow3 /k � 2 - 6 0 T c \ F o20 U 2k ° § / « a E ® • 0 Et 0 ri ƒII \ 2 f_ /\ 7 U) \ \ �I 132 E \.§ a. c2 \ .\ n ID a) e 2 ° er k k U) / 2 �» 0• 0 2J / - CD 9 5 M 2 § 0 N. / e O / 2 / / _ 0. kk a) ° § 2 OD = _ % / o \ = o 2 L k \ \ k 2 k E '(E; § 0 2 ƒ .\ a C.) _/ / 'GI \\ c § _ ■ § § Cl) \ ._ ) / � 0 Q 2 > / m CO Co) 0. 0 — o (0 0 \ Ct Q = 0_ co v _q Q § q \ ■ 0 \ CU 05 k = .2 ) ® U 165 2 k .2 / = x 0s. � q / � 2 E k q t E0 > 2 23 V 2 \ / ° - ® E ti OF TFJ • IIP 0,��\\\�//j,-sa THE STATE Alaska Oil and Gas 9a OfALACKZ Conservation Commission i tt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OgP Fax: 907.276.7542 www.aogcc.alaska.gov December 22, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit K-17 SCANNED SEP.2 0 201R PTD 1730010 Dear Mr. Golis: On December 20, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit K-17 located on the King Salmon Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit K-17 prior to the test. The well performance was monitored for three hours with no discernable flow of liquid or gas observed. The well may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit K-17 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon Platform. Sincerely, a/Wig James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission �i l2 I ZZ TO: Jim Regg i t DATE: 12/20/2015 � P. I. Supervisor FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit K-17 Hilcorp Alaska LLC PTD 1730010 December 20, 2015: I traveled to the King Salmon platform to witness a no-flow test on TBU K- 17. This well is a packerless ESP completion. Upon arrival I met with Sandy Reynolds and Chuck Morse. We discussed escape route if needed and what was happening on the platform. I listened in on their Pre-job meeting. The tubing and tubing-casing (inner) annulus were piped to be in communication prior to the no- flow test measuring equipment. I verified the Master, Swab and IA Valves to all be fully opened and test gauges attached to the Swab Valve. The pressure and flow measurement devices have recent calibrations. Flow from the meter outlet transitioned back to a 1-inch bleed hose which terminated to a bucket. The following table shows test details: 8:00 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 9:00 26/0/0 700 0 View gauges 9:00 26/0/0 700 0 Open valve to flow meter; gas bled down in 2min 30sec 9:05 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 10:05 24/0/0 700 0 View gauges 10:05 24/0/0 700 0 Open valve to flow meter; gas bled down in 2min 30sec 10:10 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 11:10 24/0/0 700 0 Open valve to flow meter; gas bled down in 2min Pressures are T/IA/OA Summary: There was no liquid flow observed during any of the bleed downs. TBU K-17 exhibited the characteristics for a no-flow determination. Attachments: Photos (5) SCANNED AUG 2 ' LUlb 2015-1220_No-Flow TBU K-17 bb.docx Page 1 of 3 • • No-Flow Test — TBU K-17 (PTD 1730010) Photos by AOGCC Inspector B. Bixby 12/20/2015 . lttut((t(l-1 i„,, /f( t( iliGtICI .A - � 't it(/' �� till ,,-,-41 La, - ',t 0 g 16 rill tir- "ft, t.;-..-444 '-. r•-:0- 4 4 .140. * -,2 MI • _ ....its.r . . Armor-Flo' Fun�r� �'' E1"l.=F ,° ':GL`5 I tE r,r IgOEI u 7110 3461-03F0-13 112377 RESUME V11SWNTY ,.:.e 1 OP 400 mu 1 (pn1(G) I $E Ilf 100.0'F OP 400"F MAX 1• ERDC0' wal lir .....r.x.unroIs.am u, a ... ... .4. 0 ..- 1, „, . ...„ *„. r 2 ( 4,„ , 8 4,444344141* Pr 10 2015-1220 No-Flow TBU K-17 bb.docx Page 2 of 3 • 0 , * 4kihdlie _ ‘ ' - . • / AlamillOyi itiN- ‘Ill I ‘1111111:- "tramillie" e \ '.''VW-.o.'' .4 ' 1" . . *ftrowe' , Nieuwe,itre .......--. ' ;41.10011"-re , • ,. NNW* • i .- .... ... 1 , . 111 ....- ..... . , .. 4...... .6 0 0 2. *;156 Y. a . ,.„ , -.. .. . i .16 .0 I t-- ,--. ' . . I . ("'.1 . ' = '' ' . . H ° I , ; ..r. i,/,If! -OK •, ,,,, , . , i rA 4;. 11.4 l' ', ., i 0 e 4 -,e - 1 It g ;e i 01 , - 1 .. , - 01) iv. .- ....ti.., jeg.% , ........ A .., ariii' l Iiir,...144 tn --. - 401 4 If ' CD el Illk. 4 (AO, ^ ' C.,,f • , .. ,. ----;-.L.• - ir. q , ifig, ma', :, 34imkgi .',,,, 1111 If Illialliv , foil" , \ ‘,.. ..• a Irv,' .,I • -- , #.• . ,,,` -• , • .7' I;" Si, ' • liT ' '. ••••,.. i lat.........i,, , • 'II ii eta. n.- ;g•0.2trai _V2 . . .. . . --. i ft i L i —...— .. -- 5„:Fii vi , - -' •. ......--j.' "--77-- -4`„'...' '• - ,..0... :_;it . f,zoatilitiar. '',--'1,- ,....____ —...... , . . '- . . , , .... .........0, ..„.:____-_,—.- ....- — , - . ... . • . . . lik*PallitailS4*. . . , rmeous,,,,,-- „,..— .. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg c-7 il4 (1 DATE: 12/20/2015 P. I. Supervisor FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit K-17 Hilcorp Alaska LLC PTD 1730010 December 20, 2015: I traveled to the King Salmon platform to witness a no-flow test on TBU K- 17. This well is a packerless ESP completion. Upon arrival I met with Sandy Reynolds and Chuck Morse. We discussed escape route if needed and what was happening on the platform. listened in on their Pre-job meeting. The tubing and tubing-casing (inner) annulus were piped to be in communication prior to the no-flow test measuring equipment. I verified the Master, Swab and IA Valves to all be fully opened and test gauges attached to the Swab Valve. The pressure and flow measurement devices have recent calibrations. Flow from the meter outlet transitioned back to a 1-inch bleed hose which terminated to a bucket. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 8:00 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 9:00 0.26/0/0 700 0 View gauges 9:00 0.26/0/0 700 0 Open valve to flow meter; gas bled down in 2min 30sec 9:05 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 10:05 0.24/0/0 700 0 View gauges 10:05 0.24/0/0 700 0 Open valve to flow meter; gas bled down in 2min 30sec 10:10 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 11:10 0.24/0/0 700 0 Open valve to flow meter; gas bled down in 2min 1 Pressures are T/IA/OA Summary: There was no liquid flow observed during any of the bleed downs. TBU K-17 exhibited the characteristics for a no-flow determination. Attachments: Photos (5) SCANNED JUL 2 7 2016 2015-1220 No-Flow TBU K-17 bb.docx Page 1 of 3 • • No-Flow Test— TBU K-17 (PTD 1730010) Photos by AOGCC Inspector B. Bixby 12/20/2015 4 ` 41(4i, tttuti ..� 111+ _ riAf( -- ,. Se,/ i ' . ., ...--. ' ow_ fiat lAlla is.fly' . N.i # I AQ, ...,:,_ , s 0 II oWim Armor-Flo' Roo '`• 11QQE1 1EMAl TAG '` 3461-03TO-13 112377 MANE Y►1COSI Y 6 r- 100 0 OP 400 MAX 1 psi(G) 100.0'F OP [4o0'F oil 1.009 P 0 • 1t 4, 10 ate= 2015-1220 No-Flow TBU K-17 bb.docx Page 2 of 3 • • . . 744ir ., ,.... , 7 rr.1 , \ ‘°41111111L.041* vt '''4411110r/ . kr. , \ .,..„ . % 4"410110.V. ,. 7111hdijk. . % -maw NIIIIMP, Nils.**•••.''''' •,,,........ 14,60,... ...„ am,. ..........1, ......., /,,,,........--,•• ,,,.... . , ..... J ...• ,... ,........ , - , . . ... ,.., 4 , 1 ,s3 „.o t--- ,--, , c'n Pq `15 E-11 m 0 0 tg ., a.. I o I (NI / /IP 4P.. csi ) . (A • 4-''' t*4'. . -1111 Ot \ • di 01) I , . voe I' : ,. ...."!: ' w, W . „...._. Ill:''...''.:1' i 4.. .".." " .1'1, ri .1 . 7. '' r MI& * .... thiliiii_ I,, '''.- i „,„...r..,' ts 4 .1,..., ...,,, I s i..t ''\. -- / i':' '''''','", - i ': i • ' ''''4',''''4,....h.,", • , . .„. Ici ' .., .,,,,, ••,, , r 84, .,,, , IP .. s Illitt i 144Nt, . .....4.. .ki.,... ' . s - , ,'' ..'......L., . . , 1 , . -77 • .."' N, . "4'„-...,1,,( •',Z e -- , f ". ,..1 . , .• ,.. ,..».' -"?.. • . -ig, ... • • - . . •,,: ... . -"'-` '-•.- - •-= - ',."."?,• ,,;; -',.... . 41,,,ada.,••'...""ii-'"*" '--.- r'r' '-"'.'. — ' ... . ‘ ,,..., STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COMM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: Replace ESP El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 173-001 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic CI Service ❑ 6.API Numbed RECEIVED Anchorage,AK 99503 50-733-20248-00 ��C 2015 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit/K-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): fid\OGG N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,120 feet Plugs measured 11,800 feet true vertical 9,787 feet Junk measured 11,676 feet Effective Depth measured 9,713 feet Packer measured N/A feet true vertical 9,713 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,193' 2,038' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner Perforation depth Measured depth See Schematic feet SCAMEO 1-r 0 ,:;:j1.6 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/IMP BTC MOD 9,680'(MD) 7,893'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 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: 161 107 6691 68 70 Subsequent to operation: 73 81 7732 70 70 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations (] Exploratory❑ Development Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ❑ SUSP❑ 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: 315-610 Contact Dan Marlowe(907)238-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis `} ,�(� Title Operations Manager Signature �J -�--"�-� 0 `. Phone (907)777-8356 Date t 2 /I LI 7/5— , ... /7, ... /z-Zi—,5— , `4„`z4-�� RBDMS DEC 2 .12015 Form 10-404 Revised 5/2015 Submit Original Only . • King Salmon Platform SCHEMATIC Well # K-17 ,,,eo,P,,,Rk„ ,,, Completion:12/07/2015 1B=100'ANhL CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 11 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9-5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 133/$" 2183' 9-5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' Tubing: 4-1/2" 12.6# IMP BTC MOD 3.958 Surf 9,680' Note: When pulling tubing-must pull singles ,t engchnsge 7816'-7,826' CenertStd6/2014 JEWELRY DETAIL No. Depth(MD) Depth(TVD) ID Item 33.7' 33.7' Hanger wr1 ;t C3sirdanayt 1 9,680' 7,893' - Discharge,Bolt-On r �nertStd& 14 2 9,681' 7,894' - Pump(x2)Summit 675 Series,045 Stage 3 9,725' 7,930' - Intake 1 4 9,744' 7,946' _ - Motor(x2)Sumit 562 Series(Used) II 5 9,815' 8,004' - Centralizer/Anode 2 6 11,800' 9,537' CIBP 3 la mow PERFORATION DATA 4 It Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) Amt Comment 5 It G-1 10,828' 10,846' 8,793' 8,806' 13 Open G-2 10,878' 10,907' 8,830' 8,852' 22 Open G-2 10,922' 10,946' 8,863' 8,881' 18 Open G1-6 G-3 10,990' 11,007' 8,913' 8,926' 13 Open G-4 11,040' 11,086' 8,950' 8,984' 34 Open G-4 11,127' 11,139' 9,015' 9,024' 9 Open G-5 11,183' 11,249' 9,057' 9,107' 50 Open H34,2,3,4 G-6 11,318' 11,350' 9,160' 9,185' 25 Open HK-1 11,419' 11,457' 9,238' 9,268' 30 Open 40 HK-1 11,420' 11,460' 9,239' 9,270' 40' 6 CIBP @11,90YM) HK-2 11,482' 11,539' 9,288' 9,332' 57 Open Fil . .?S I IE-5-SW HK-2 11,482' 11,540' 9,288' 9,333' 58' HK-2 11,551' 11,584' 9,342' 9,374' 33 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' 21)* , HK-3 11,592' 11,655' 9,374' 9,423' 63' HK-3 11,595' 11,646' 9,376' 9,416' 51' Open 1B6 HK-4 11,655' 11,774' 9,423' 9,517' 119' HK-5 11,856' 11,876' 9,581' 9,597' 20' SQZD ,•,,,-' ,„--,t ' r HK-6 11920 11,975' 9,631' 9,674' 55' 4Y.rr` tt. 3 ,,' , 1 1'"�'\ 95/8"csg Fish: PBTD=u075 ID=12,120' 11,676'-Partial Bridge Plug MIX HOLE PN3LE-44°@ 11,688'-Obstruction ESP remaining in well above CIBP Updated by:JLL 12/11/15 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-17 Moncla 404 50-733-20248-00 173-001 11/27/15 12/7/15 Daily Operations: 11/27/2015 - Friday Install BPV and N/D tree. Prep well head and inspect hgr threads. M/u sub 11 1/2 turns by hand.Terminated control lines, checked penetrator cap. Stack 13-5/8" riser, mud cross, bops and Hydril. N/U bops and secure stack. Lower rig floor and rig up same. Start winterizing bops, install wind walls on rig floor and run heater ducts to same. Finish winterizing misc. rig equipment. 11/28/2015-Saturday Finished R/u floor. R/u BOPE tarps. R/u tongs. M/u 3 1-2 t/j, ck& mark acc. bottles, pressure good. Install 1 rig cover, unable to install others f/wind. Filled stack& shell tested. Repaired leak on uni-bolt connection, pressured up, cont. isolating leak t/stack. Pull t/j, re-tape/dope. Rih, appears sub might be shouldering on hanger neck. Re-configure t/j. Continue pre-testing bops and surface equipment, repairing leaks as needed, prior to state witness. Unable to fly out (AOGCC) inspector due to weather. R/U circ. hose to Trading Bay to clean out well. Perform general housekeeping and re-inspect all rig components for compliance. 11/29/2015-Sunday Cont. housekeeping while waiting f/state hand to arrive. PJSM f/testing BOPE.Tested BOPE as per Hilcorp/AOGCC Requirements.Test witnessed by AOGCC inspector Brian Bixby.Tested 250 low, 2500 high as per sundry, w/3 1/2 &4 1/2" t/j's. Had 1 F/P w/blind rams. L/D tj. M/u landing jt. R/u &circulate to production/Trading Bay. PJSM. Circulate @ 2.6 BPM, 900 psi. Shut down pumping f/leak on pulsation dampener. Cont displ. well w/8.5# F/I.W. @ 2.6 bpm 900 psi. All returns going to Trading Bay. Total pumped= 750 bbls. Blow down lines. R/d circulating hoses and held PJSM w/all essential personnel on pooh w/ESP ass'y. Back out hgr pins, pull hgr to rig floor.Terminate electrical cable and control lines. Summit check cable for continuity (showing ground). Laydown hanger and rig up sheaves in derrick. POOH w/4-1/2" 12.6#production tbg and jewelry. 11/30/2015- Monday Cont. POOH L/d 4 1/2 completion. Recovered 345 jts. Found collars on jts 325, 326, 327 had corrosion. POOH L/d pump, seal & mtr assembly, checking components as pulled. Initial look, pumps turned good, suction screen was collapsed. Wire & lead tested good. Upper mtr showed ground, lower mtr good. Water in seals, anode approx 50%. 12/01/2015-Tuesday • Finished L/d motor. R/d ESP pulling eq. c/o handling eq. Cleaned &cleared floor, drill deck. M/U c/o BHA-8 1/2 bit, 9 5/8 scraper, bit sub = 7.82. RIH P/u 3 1/2 PH-6 wk string t/ 10,018', up wt 110k, do wt 68k. • • • ligin I Hilcorp Alaska, LLC I Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-17 Moncla 404 50-733-20248-00 173-001 11/27/15 12/7/15 Daily Operations: 12/02/2015-Wednesday Cont. tih t/10,708 tag, up wt 114, dn wt 65k, attempt t/wk through , no go.Arrange deck. P/U swivel & m/u. Attempt t/wash down @ 2.6 BPM rev. 360 psi, no go, rot @ 45 rpm, 4200 off, 5300on, rot wt 93k. Wash & ream down t/10, 718'. CBU clean @ 2.6 BPM, 380 psi,getting back solids. Blow down. L/d swivel. Pooh with 3-1/2" ph6 and bha. L/D scraper. Blow down lines. N/D riser. N/U stripper head spool and riser. M/U 8.5" bit, bumper/oil jars and (6) 4-3/4" dc's. Strap and caliper same.Total BHA length= 212.58'. C/o handling eq. tih w/3-1/2" PH6 and clean out ass'y.Tag @10,718' dpm, P/U 125k, 5/O 70k. Install stripper rubber and r/u power swivel. 12/03/2015-Thursday Cont. r/u swivel. Wash & ream f/ 10,718't/10,815' circ. @ 2.6BPM, 430 psi, up wt 120, dn 74, rot wt. 92k, 5200 tq. off, 62-6700 on, 5-8 WOB. CBU each jt.getting solids in returns. Fluid loss 25 BPH. Broke through bridge @ 10,815'. Lost returns temp,gained returns, CBU @ 2.6 bpm, loss rate @ 60BPH, at B/U got oil returns. R/u t/circulate t/production/Trading Bay. Circ. 2.4 BPM, 560 psi.Total pumped=675 bbls. L/D POWER SWIVEL AND CONT TIH W/3- 1/2" PH6 TAG @11,183'. N/D RISER SPOOL AND N/U STRIPPER HEAD ADAPTERS. R/U POWER SWIVEL AND EST DRILLING PARAMETERS. ROTATE AND WASH DOWN FROM 11,183'- 11,260' PUMPING AT 3 BPM, 300 PSI,TORQ=5- 5500 OFF/62-7000 ON, RPM=50, WOB= 5-10K, ROT P/U= 105K S/0= 98K 320 PSI. ALL PUMPING DONE IN REVERSE. C/B/U EACH JT DOWN. 12/04/2015- Friday Cont. wash & ream, 1/11,260' t/11,279', circ @ 3BPM, 290 psi, rot 50 rpm, tq off 5700, on 6700, rot wt 103k, rop dropped t/ 15' hr. loss rate @ 120BPH while pumping. CBU @ 3.5 BPM, 300 psi. L/D swivele &strip off halls head flange. Monitor&fill hole. Static losses 45 BPH. POOH L/D 3 1/2 PH-6 wk string. L/D BHA— assy.� 12/05/2015 -Saturday Clean &clear floor. C/o handling eq. M/u test jt. Fill stack, shell test. Test BOPE as per Hilcorp/AOGCC Requirements. Early test& witness waived by AOGCC inspector Jim Reg @ 3:35 pm on 12/4/2015.Tested 250 low,ZSOQhigh as per sundry, w/4 1/2" t/j. All good. R/d test jt, blow down all surface lines. PJSM w/all involved. R/u &start p/u SLB/Summit ESP assy& service.Tih w/4-1/2" 12.6# IMP BTC prod tbg and ESP assy. Strap and rabbit same. Checking continuity every 1,000'. Depth at report time= 2,512'. 12/06/2015 -Sunday Cont. tih p/u 4 1/2" 12.6# Butt. tubing, t/4,980'. Meg cable &test cap. lines every 1,000'. C/o cable spools, splice & test same, good. Cont. tih p/u 4 1/2" 12.6# Butt. tubing, t/9,780'. Meg cable &test cap. lines every 1,000'. M/U HGR. Install penetrator and meg same. Install ctrl lines. Land hgr and run in L/D pins. P/U Wt# 135k S/0 Wt#78k, bottom of assy @ 9,816'. RID landing jt. Install BPV. R/D ESP running equip. Clear floor& r/d. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-17 Moncla 404 50-733-20248-00 173-001 11/27/15 12/7/15 Daily Operations: 12/07/2015 - Monday Finish R/D floor. N/D BOPE. N/U tree adaptor.Test void t/5000,good. Cont. N/U tree, test t/5000, good. �pF T� w 1' %%i,9 THE STATE. Alaska Oil and Gas ®fAS Conservation Commission Atst# KA. 333 West Seventh Avenue 2 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov November 25, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit K-17 PTD 1730010 Dear Mr. Golis: On August 22, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit K-17 located on the King Salmon Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit K-17 prior to the test. The well performance was monitored for three hours with no discernable flow of liquid or gas observed. The well may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit K-17 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon Platform. Sincerely, jct'U1 ':1ercf James B. Regg r Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors P,,of Tye • • �w w��\\ �9 THE STATE Alaska Oil and Gas ��, ofA LAsKA Conservation Commission t4P.t2 y,` :_ 333 West Seventh Avenue \Tye; GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS"' Fax: 907.276.7542 p� 06 www.aogcc.alaska.gov Stanley Golis Operations Manager 1 7 3 0© 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-17 Sundry Number: 315-610 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this I7d ay of November, 2015 Encl. • • CE Y En STATE OF ALASKA NOV 12 20b ALASKA OIL AND GAS CONSERVATION COMMISSION as r4 It 'Mc APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well E • Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing El Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Replace ESP (' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ` Exploratory ❑ Development 2 - 173-001 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20248-00• 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No L ✓ Trading Bay Unit/K-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,120 , 9,787 . 12,025 , 9,713 200 psi(shut-in) 11,800 11,676 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,038' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6#/IMP BTC 9,871 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary 2 Wellbore schematic ( 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development[ • Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/13/2015 OIL 0• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR Cl SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Ted Kramer(907)777-8420 Email tkramer(c�hilcorp.com Printed Name Stanley Golis Title Operations Manager Signature C ��"� Phone (907)777-8356 Date 11/12/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 6- (e 10 Plug Integrity ❑ BOP Test V. Mechanical Integrity Test ❑ Location Clearance El Other: ie ZTDCS , 4.-.7, ,-/) --r-z3,- ( MPS/°= 2 /-rc") Post Initial Injection MIT Req'd? Yes ❑ No ❑ IiIn\1 1 iii 1015 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /©` -7 0 / RBT MS // APPROVED BY Approved by: 9 �L�-___ COMMISSIONER THE COMMISSION Date: /f-( 7 - is let_ 11 i 15- .", . W/7.0--- fP41 lillsk 0416444d Subs in Form ane Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate RECEIVED STATE OF ALASKA SEP 2 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Replace ESP - 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 173-001 ' 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20248-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay Unit/K-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 . McArthur River Field/Hemlock Oil&Middle Kenai G 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): 12,120 - 9,787 - 12,025 - 9,713 11,800' 11,676' Casing Length Size MD TVD Burst Collapse Structural Conductor N Surface 2,183' 13-3/8" 2,183' 2,038' ., „./9 ,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner ,+ Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6#ItLMP BTC 9,871' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 X13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ tvelopment 0. Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 10/13/2015 Commencing Operations: OIL 0 . WINJ ❑ WDSP❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTO❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned It 17. I hereby certify that the foregoing is true and correct to the best of my knowt'edge. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name�jG.,s Ted kramer T.fe Sr.Operations Engineer Signature �/ /� (� �� Phone / (907)777-8420 Date 9/28/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a represent ive may witness Sundry Number: 316- b\o Plug Integrity ❑ BOP Test V Me anical Integrity Test ❑ Location Clearance ❑ . Other: Z 8'Z) /0.5o f' l� r— ( , i't4 P 46?- Spacing Exception Required? Yes ❑ No I Subsequent Form Required: /G -- ll0 c 1 11 r j APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 14% I/3a IS cii,,' /tit.ir ORIGINAL . .9r if Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Well Work Plan Well: K-17 Ililcoru Alaska,LL Date:09/28/2015 Well Name: K-17 API Number: 50-733-20248-00 Current Status: ESP Lifted Producer Leg: Leg#1 NE Corner Estimated Start Date: October 13, 2015 Rig: Moncla 404 Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 173-001 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 3,550 psi @ 8,700'TVD 0.41 lbs/ft(7.85 ppg)from gauge on ESP Maximum Expected BHP: 3,550 psi @ 8,700'TVD 0.41 lbs/ft(7.85 ppg)from gauge on ESP Max.Anticipated Surface Pressure: .Q-psi- - w e tO8722/T5)-will not flow basted on an oil and water gradient of 0.417 psi/ft. Well Summary The K-17 is an oil well producer which is currently on ESP artificial lift. The ESP failed on a restart attempt September 23, 2015. Well Objective This workover will replace the failed esp. Last Casing Pressure Test: 06/05/2014 at 7,816' to 1500 psig for 30 minutes Procedure: 1. MIRU Moncla Rig 404. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to +/-9,800' and punch tubing. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. POOH with tubing string and ESP pump laying down the same. 5. RIH with cleanout assembly to +/- 11,700', Circulate well clean, POOH. . 1 6. PU, RIH with ESP completion. - `"'`; `.'Ay „/ J 7. Land ESP with the bottom of the assembly at +/- 10,000'. ° 8. ND BOP, NU wellhead and test. 9. Turn well over to production. 10.RDMO Rig. • • la Well Work Plan Well: K-17 Hilcoru Alaska,LL Date:09/28/2015 Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Drawing/ Proposed Wellhead Drawing (Same) 4. BOP Drawing • . King Salmon Platform SCHEMATIC Well # K-17 Il,lemP AleEke,LLCCompletion: 06/30/2014 1B=10(P ANSI, CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1..i 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9-5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 1338 @183' 9-5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' Tubing: 4-1/2" 12.6# IMP BTC 3.958 Surf 9,871' Casing damage 7,81e_7,826' JEWELRY DETAIL Cenent Sz'd 6/2014 No. Depth(MD) Depth(ND) ID Item 1 33.7' Hanger 2 9,872' 8,050' Bolt-On Discharge Casing dame 3 9,874' 8,052' Pump(x3) 675 Series,039 Stage,SH10000 9,098' . CematSLd6,2D14 4 9,928' 8,096' Seals 2 5 9,946' 8,110' Motor(x2)562 Series,KMP1,340 HP 31 6 10,010' 8,161' Centralizer/Anode „But� 7 11,800' 9,537' CIBP 4 5 ' PERFORATION DATA 6 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comment G-1 10,828' 10,846' 8,793' 8,806' 13 Open G-2 10,878' 10,907' 8,830' 8,852' 22 Open G1-6 G-2 10,922' 10,946' 8,863' 8,881' 18 Open G-3 10,990' 11,007' 8,913' 8,926' 13 Open G-4 11,040' 11,086' 8,950' 8,984' 34 Open G-4 11,127' 11,139' 9,015' 9,024' 9 Open HB-1,7.,3,4 Open G-5 11,183' 11,249' 9,057' 9,107' 50 0 G-6 11,318' 11,350' 9,160' 9,185' 25 Open HK-1 11,419' 11,457' 9,238' 9,268' 30 Open 7 11111.1" "" °_ - CIS@11,8110'ND HK-1 11,420' 11,460' 9,239' 9,270' 40' II-BS-SQ D HK-2 11,482' 11,539' 9,288' 9,332' 57 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' HK-2 11,551' 11,584' 9,342' 9,374' 33 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' ' HK-3 11,592' 11,655' 9,374' 9,423' 63' HK-3 11,595' 11,646' 9,376' 9,416' 51' Open 13-6 HK-4 11,655' 11,774' 9,423' 9,517' 119' HK-5 11,856' 11,876' 9,581' 9,597' 20' SQZD HK-6 11920 11,975' 9,631' 9,674' 55' A 4•":„r q,f' >*",./‘‘...:4::.,0,''' 95/8"csg Fish: P6TD=12,025 ID=12,120' 11,676'-Partial Bridge Plug M HOLEANaE-4�@� 11,688' Obstruction ESP remaining in well above CIBP Updated by:JLL 07/29/14 • . King Salmon Platform . H Proposed Well # K-17 Hilcorp Alaska,LLC Completion: Future KB=100'AMSL CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9-5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 133/8"*2183' 9-5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' Tubing: 4-1/2' 12.68 IMP BTC 3.958 ±9,850' Casing 7,816'_7,826• JEWELRY DETAIL Cement Std fi12D14 No. Depth(MD) Depth(TVD) ID Item 1 33.7' Hanger 2 ±10,000' ±8,153' Bottom of ESP Casing darrage 3 11,800' 9,537' CIBP Cerra t Std 6"2014 i .r PERFORATION DATA 2 CI Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comment G-1 10,828' 10,846' 8,793' 8,806' 13 Open G-2 10,878' 10,907' 8,830' 8,852' 22 Open G1-6 G-2 10,922' 10,946' 8,863' 8,881' 18 Open G-3 10,990' 11,007' 8,913' 8,926' 13 Open G-4 11,040' 11,086' 8,950' 8,984' 34 Open G-4 11,127' 11,139' 9,015' 9,024' 9 Open I-IB-1,2,3,4 Open G-5 11,183' 11,249' 9,057' 9,107' 50 G-6 11,318' 11,350' 9,160' 9,185' 25 Open HK-1 11,419' 11,457' 9,238' 9,268' 30 Open 3 a1I@11,800'MD HK-1 11,420' 11,460' 9,239' 9,270' 40' IIB5_8QVD HK-2 11,482' 11,539' 9,288' 9,332' 57 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' HK-2 11,551' 11,584' 9,342' 9,374' 33 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' .„1..74 ', HK-3 11,592' 11,655' 9,374' 9,423' 63' HK-3 11,595' 11,646' 9,376' 9,416' 51' Open }6'6 HK-4 11,655' 11,774' 9,423' 9,517' 119' HK-5 11,856' 11,876' 9,581' 9,597' 20' SQZD "' ', "r`:..°4; HK-6 11920 11,975' 9,631' 9,674' 55' J.Z,?.:,;,'',°';':'-',.'''. r''i.,r. I.':tq"% A' ''';*yR\ 95/8"csg Fish: PM-D=12025' Tp_12, 11,676'-Partial Bridge Plug M3<HOLE ANGLE_44 @3830. 11,688' Obstruction ESP remaining in well above CIBP Updated by:ILL 09/28/15 , II King Salmon Platform K-17 03/18/2014 Ifilrnrp:tlrxrka.1.1.0 King Salmon Tbg hanger,OCT-UH-TC-1A- K-17 ESP,13 X 4'A IBT lift and 24 X133/8X95/8X4'/ susp,w/4"Type H BPV profile,3/8 cont control line port BHTA,Bowen,4 1/16 5M FE x 7"-5 Stub acme Bowen top Ifl 'rr 1 1 Valve,Swab,WKM-M,4 1/16 5M •,00) �> FE,HWO,EE trim o C Valve,Wing,SSV,WKM-M,3 1/8 5M U L FE,w/OMNI oper,EE trim Valve,Wing,WKM-M,2 1/16 5M FE,HWO,DD trimN /1—K- i •,Q'-' ., - -_-i_ Lj j N _ rrnr �l —1111111.1 Valve,Master,WKM-M,4 1/16 5M tu:i Vcwifiri Nu FE,HWO,EE trim N _ 0 IQI I UI ..U%v 0 �<...,�r iimidiaalrEi Valve,Wing,WKM-M,3 1/8 5M FE, xi. HWO,EE trim I EA1111140Adapter,OCT-A5-ESP,13 5/8 5M API hub in-= m X 4 1/16 5M stdd top,w/2-''/control off. line exits,prepped w/OCT 400-4 pocket [=,n r ! '1 • • • King Salmon Platform BOP Stack(Moncla) Hilrnrp,Vnsko,l,IA • v Iti 111 NI ill I/1 1I1 II III 3.74' Shaffer 13 5/8 5M , 111 tit !film I I t!I #II I!I tEl lit ow-u "mu- __ — - -- �_ Variable 27/8-5 4.67' .••• + 13 5/8-5000t �u Blind Rams lil=lilail.iit III Choke and Kill Valves 21/16 5M w/Unibolt connections for hoses a Igrill"' IU 1 1 - . 2.00' 1Ir I!O1J lN 13 5/8-5000 G ;�1. zA__Di II-V FU UT] Liif Riser,13 5/8 5M FE X 13 5/8 5M API#13 hub 13.70' • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLCAttachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure • • • Moncla Rig 404 BOP Test Procedure Hacorp ni,.ka, Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt.of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. • Moncla Rig 404 BOP Test Procedure Haeor,,ni,5ka,IAA' Attachment#1 d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3,4, 9. After test,open valves 3 &4. Leave 9 closed. iii) Valves 5, 6,9. After test,open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test,open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • . II Moncla Rig 404 BOP Test Procedure nn oip Al ka,r.l.r; Attachment#1 Diagram B: Choke Manifold it)Gas Buster All National typo To Panic line 2 1/16 5M 1502 Union ball valves �f f I, II li* - , L �I . 114 Chokes are 90 degrees off 40.41). t in drawing in order to show detail I= :IN moo 1111 II; I1 !I ivo IIIA i riir• _ ' f 110ii ,11611 :__, E440.--1F4. Inc n _Swaco Num M . f ll 3 : . • I I - III ._ . ,tial 11E41 WI 1 I II NM I. Iiiii cq n iJ Ih-.__.--„ A-- III 1 1, ,k 11 fll i _ I From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve 63260,3 %" Ball port,6000psi working pressure #2 National Ball Valve B3260,3 '/;'Ball port,6000psi working pressure #3 National Ball Valve B2650, 2 9/16"Ball port,5000psi working pressure #4 National Ball Valve B2650,2 9/16" Ball port,5000psi working pressure #5 National Ball Valve 62650,2 9/16"Ball port,5000psi working pressure #6 National Ball Valve B2650,2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve 62650,2 9/16"Ball port, 5000psi working pressure #8 National Ball Valve 82650,2 9/16"Ball port,5000psi working pressure #9 National Ball Valve 63260,3'/;' Ball port,6000psi working pressure #10 National Ball Valve B1560, 1 '/2" Ball port,6000psi working pressure C O U r— • O V o V o 0 0 0 0 o V O V o V V o V u o 2_ o �fl 5 l0 5 n 5 N 5 m 2 2 2 2 2 5 m 5 5 5 it g a a a a a: - V U V V V V V V V O ,-.1a lf M 1 0 ,-+ N T V Vl CD N o0 m , -O -o "0 V 91 p -0 -0 , V M O -0 , -0 -0 C000 O, 00000OO Y 5 - . . , Y ' C C C C C C C G C O S ' g 555Wm > _I522222 222 > y a a a a a C C > Y: N Y Y Y Y Y Y ` 5 2 E E E E E! of 1,1 -5 -5T, 01570000 -62 ',v JJ= U L L L L L L L L L L L J >• 2 a. a s ai Y Y = V V V V V U V V V U V N .c : N of t .`G o 01 0 0 ; o0 0 A' 5N O) 4 r , 00 CO 4i U Z z n� G -1 J ry UJ Q LLI a a 0 M z O i U y O 2 V E -V) w U Q K => O cc O a0 LL a Q Ei.w ii CU i ti VEMIIIMIIIIMMMIIIIII 11 •� I CL 0 0 Q m ►- V) w H a Y. • 0 z CO CO Q J z 0 Z 1-7-w Z ajz Q 0CI JtnJ 0LI H a • 1 Z ooepV } coag -- 0wZC0 Qua z —100 °90 UJ Jr- . Zp g ZI I H LLZin "m a Z 0 5 _I lirD U 0 O + `-' O O U O U' 00 . 0 OUOO0U0UU0UU 0 • o _, I o ry m v m•.. "' ry m e LO to n CO m 5 aa a a a U U U U U U U U U o m V LII,- V .-1 Pc m a Li) 10 n CO Cr, r+ -o v v v 0 ': p 'O 'O v -o "O 'O t V -0 'o 0 0 0 0 L 1flh1H ! Hfl CGCCCV Y y O. O. O. 6j Y > g E E E E E LL o 0 0 0 0 0 0 0 0 0 o a L w > d d 1 1 1 X a S V 6 6 U 6 U V U V V V N 5 m -O V O O -43O O i Y .t O 2 'C 2 0 LO L LL V {J Y V K O qk ,1 t1 cv Cr) OW a? a a0 M . st . Zo NU .._ 2U '----H-_4 X 0 0 w /^' 0 w / X> OE TU� 7 in,...._ 1-111 LIG" iiii _i_[ Ott T Y o m H v) IA H a E III 0 z ,_ u) z 0 0 Z Uw Z CO 0� -.44aU)� H El2a L Z Pi- (3_ m c O 0 E- - U � z _j � ... U cc 0 Z UL_ JOU N 14- o o o r( J O Z r`)i., N W a N IL Z Hry J o m = Q p 1- -J 0 D 0 U ® L ce 1 t' 0 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, November 10, 2015 12:23 PM To: 'Ted Kramer' Cc: Juanita Lovett Subject: RE: K-17 RWO to change out ESP Ted, Looking at the sundry.. need a flow diagram for the fluid system on Moncla 404. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Monday, November 09, 2015 2:50 PM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: K-17 RWO to change out ESP Guy, This Sundry Application is one of the last Sundrys you have that was submitted prior to the shutdown. I would like to get this one moving since we plan to move to this well after the M-17 which we are rigging up on now. In response to our earlier discussion, I have reviewed the Sundry procedure and admittedly, it is pretty Spartan but then this is an ESP swap and therefore it is pretty straight forward. We are going to pull the failed ESP, make a run with a mule shoe to tag for fill, and then run the new ESP. The max Anticipated Surface pressure is shown to be zero and I know you said not to have zero. I have checked with the field, and the surface pressure on the tubing and the casing are both 200 psi. Since this is a no flow well, I would change the zero to 200 psi but there is not much else I would change. Please take a look and let me know what it will take to get this Sundry moving and approved. If we need to discuss, please call me or let me know by e-mail and I will be happy to call you. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 1 • STATE OF ALASKA • AL, ,A OIL AND GAS CONSERVATION COMI\,.._SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well LI Other: __ Li 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development L Exploratory❑ 173-001 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic LI Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20248-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 ` Trading Bay Unit/K-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): - N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: \A Total Depth measured ., 12,120 feet Plugs measured 11,800 feet EC E IV E D true vertical 9,787 feet Junk measured 11,676 feet AUG 2 8 2015 Effective Depth measured 12,025 feet Packer measured N/A feet true vertical 9,713 feet true vertical N/A feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,038' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner Perforation depth Measured depth See Schematic feet NED SEP 1 7 2-015 True Vertical depth See Schematic feet CAN Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/IMP BTC 9,871'(MD) 8,050'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10,828-11,688 Treatment descriptions including volumes used and final pressure: 330 gallons WAW-5206,990 gallons xylene blend,98 bbls 15%hydrochloric acid, 215 bbls FIW displacement. Final pump pressure 1,200 psi at 1.40 bpm 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 171 127 7030 75 70 Subsequent to operation: 188 115 6465 42 66 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ 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: 315-455 Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature -/(0.i - -,67( ) r 17 filar/peVe_'hone (907)283-1329 Date 8/28/2015 Form 10-404 Revised 5/2015 RBDMSZ "AUG 3 1 2015 2A-17.3 /S/ Submit Original Only King Salmon Platform SCHEMATIC Well # K-17 ,�„M P�,,£ka ,,,: Completion: 06/30/2014 KB=100'A1 N.., CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 MEW 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9-5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 133x$ @21ffi' 9 5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' • Tubing: - 4-1/2" 12.64 IMP BTC 3.958 Surf 9,871' Casing damage 7,816'_7,826' JEWELRY DETAIL Ca 1Sid&Z 14 No. Depth Item 1 33.7' Hanger 2 9,872' Bolt-On Discharge Casing dairage Pump(x3) 675 Series,039 • 3 9,874' Stage,SH10000 03Tet&d6r2014 • 4 9,928' Seals 2 >! Motor(x2)562 Series, 3 111 5 9,946' KMP1,340 HP ,i, 6 10,010' Centralizer/Anode 4 7 11,800' CIBP 5 PERFORATION DATA 6 - Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comment G-1 10,828' 10,846' 8,793' 8,806' 13 Open G-2 10,878' 10,907' 8,830' 8,852' 22 Open G1-6 G-2 10,922' 10,946' 8,863' 8,881' 18 Open G-3 10,990' 11,007' 8,913' 8,926' 13 Open 6-4 11,040' 11,086' 8,950' 8,984' 34 Open 6-4 11,127' 11,139' 9,015' 9,024' 9 Open 113-1,2,3,4 Open 6-5 11,183' 11,249' 9,057' 9,107' 50 6-6 HK-1 11,318' 11,350' 9,160' 11,419' 11,457' 9,238' 9,185' 9, 25 30Open 2 Open 68' 7 lamGBP@11,806'111D HK-1 11,420' 11,460' 9,239' 9,270' 40' 5//h . .?ligl I I-BS-c,D HK-2 11,482' 11,539' 9,288' 9,332' 57 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' HK-2 11,551' 11,584' 9,342' 9,374' 33 Open '= " HK-2 11,552' 11,592' 9,342' 9,374' 40' HK-3 11,592' 11,655' 9,374' 9,423' 63' HK-3 11,595' 11,646' 9,376' 9,416' 51' Open 1B6 HK-4 11,655' 11,774' 9,423' 9,517' 119' HK-5 11,856' 1 11,876' 9,581' 9,597' 20' SQZD HK-6 11920 11,975' 9,631' 9,674' 55' . ' A .- ',► 9558"68 Fish: PBTD=12,025, TD_u 11,676'-Partial Bridge Plug M3xFICLEANGLE-44 @39210' 11,688' Obstruction ESP remaining in well above CIBP Updated by:JLL 07/29/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 173-001 8/4/15 8/6/15 Daily Operations: 08/04/2015-Tuesday Shut-in K-17 ESP and allow to equalize. Held pre-job safety meeting, rig up pump and equipment, mix pre-flush chemicals. Pressure test discharge line to 500 low, 2,000 high. Fill well with 161 bbls FIW. Pump 330 gallons WAW-5206,990 gallons xylene blend. Pump 98 bbls 15%hydrochloric acid. Pump 215 bbls FIW displacement. Final pump pressure 1,200 psi as 1.40 bpm. Shut-in for 6 hour soak. Returned to production at 08:00 08/05/2015. 08/05/2015-Wednesday Complete 6 hour acid soak. Start ESP and flow back 550 bbls to cleanup well. Fill wellbore with 162 bbls FIW. Pre mix preflush. Pump 170 bbls preflush.(10 drums WAW-5206 mixed with 158 bbls FIW). Pump 367 bbls Scale Inhibitor batch. (36 drums SCW-4004 mixed with 320 bbls FIW). Begin displacing with 890 bbls FIW.700 pumped at report time. 08/06/2015-Thursday Finished pumping 690 bbls FIW. Final rate 1.2 bpm at 1200 psig. Shut-in well for 12 hour soak. Rig down equipment. Return well to production. • i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ,(\ TO: Jim Regg 1-47/1 DATE: 8/22/2015 P. I. Supervisor FROM: Johnnie Hill SUBJECT: No Flow Test Petroleum Inspector King Salmon well K-17 Hilcorp Alaska LLC PTD 1730010 8/22/2015: I traveled to the Trading Bay Unit King Salmon Platform to witness a no-flow test on well K-17. This well is a packerless completion. Upon arrival I observed the well rigged up as follows: - Tubing and tubing-casing (inner) annulus were piped to be in communication prior to the no-flow test measuring equipment; - Commingled flow from TBU K-17 was routed through a 1/2-inch hose to a 3/-inch flow tee with a 30psi test pressure gauge on top and a 3/-inch ball valve in the flow stream ahead of an Erdco ArmorFlo meter (ID #9916323461-03T0-11). The pressure and flow measurement devices have recent calibrations. Flow from the meter outlet transitioned back to a 1-inch bleed hose which terminated in a partially water-filled barrel. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 9:30 0/0/0 0 0 open 10:00 0/0/0 0 0 closed 10:30 0/0/0 0 0 open gas unmeasurable 11:00 0/0/0 0 0 open; gas unmeasurable 11:30 0/0/0 0 0 open 12:00 0/0/0 0 0 open 12:30 0/0/0 0 0 open 1 Pressures are T/IA/OA Summary: TBU K-17 exhibited the characteristics for a no-flow determination Attachments: 2 pictures Ci�NNE® AUG 2 2 ZUiu 2015-0822 No-FtowT B U_K-17,j h.do cx Page 1 of 2 • • No Flow Test- TBU K-17 (PTD 1730010) Photos by AOGCC Inspector J. Hill 8/22/2015 r t f �EP .�' s ‘00004....4 ,, ' , -174 I, '( a %6 �e / r 1 4. 4 . ill' .-,,i1 .,, - -.,:1611.11:010 Arty)°,-Flekt t MOEML SERIAL TAG -. VISCOSITY PRESSURE iCi(i3O p►I 4(i0►yt)( us1(G) . ..„ .. ,, : . • I IEMPCOIITUNE SGS. f(1U.U"'FOP I 4Ut)"F MAX I11 EROCO" EVANSTON.ILLINOIS 60192 SSP _' *411. .1. iii .' ' `0. 11.11. # , rT ` '\\\\\ , .,7 6 Att A 10 12 14 k< SCFHt100 i .......m1010.11.1° r. 2015-0822 No-F1ow_TBU_K-17_jh.docx Page 2 of 2 rtrOF TM /7, THE STATE Alaska Oil and Gas vf1' Lj\ S Conservation Commission KA %mot =__ ^_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 °'s' F Main. 907 279 1433 ALAS ' Fax 907 276 7542 ��A'p��-� www.aogcc alaska gov Dan Marlowe 3' 0 d 1 Operations Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU K-17 Sundry Number: 315-455 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, la4f Cathy P.7 . Foerster Chair DATED this C.*of July, 2015 Encl. RECEIVED JUL 272015 STATE OF ALASKA ars 71 IA)J is ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCL APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate EI(Acid) Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: - ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC - Exploratory ❑ Development 0 . 173-001 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic E Service El6.API Number: Anchorage,AK 99503 50-733-20248-00 . 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 E Trading Bay Unit/K-17 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil&Middle Kenai G 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): 12,120 9,787 12,025 9,713 11,800' 11,676' Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,038' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6#/IMP BTC 9,871' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ uvelopment❑' ' Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 8/10/2015 Commencing Operations: OIL E ' WIND ❑ WDSPE Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOLI SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature .a2_ i.6k ,. Phone (907)283-1329 Date 7/27/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316 — 1-1 Plug Integrity El BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ L, Other: , Spacing Exception Required? Yes CI No I2 Subsequent .-/ ci Subsequent Form Required: 1 c At / APPROVED BY Approved by: I 2.COMMISSIONER THE COMMISSION Date: -2- 8 _( • ' / ?-ZP'--/s ?ir_ ' I'S OfIGIN Q RRDMS� AUG - 2 2015 1 / 1 L ,' r�Lr� Submit Form and Form 10-403 Revised 5/2015 ooroved aoolication is valid for 12 months from the date of aooroval. Well:Well WorkK-17 Plan Hilcorp Alaska,I.0 Date:07/27/2015 Well Name: K-17 API Number: 50-733-20248-00 Current Status: ESP Lifted Producer Leg: Leg#1 NE Corner Estimated Start Date: August 10,2015 Rig: N/A Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 173-001 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 700 psi @ 8,700' TVD ESP Intake Gauge Maximum Expected BHP: 4314 psi @ 8,700' TVD (ESP intake Gauge). Well SIBP of 2314psi plus 2000 psi pump pressure. Max. Anticipated Surface Pressure: 1800-2,000 psi treatment pump pressure limit Well Summary The K-17 is an oil well producer which is currently on ESP artificial lift. Total fluid production from this well has decreased substantially since the June 2014 work over. This decrease is believed to have been caused by scale formation in the well bore and perforation tunnels. Well Objective Hilcorp plans to pump an acid soak down the production tubing and across the perforations to clean up any scale deposition. -.a -ot.�i.re'`— 3ts',z Procedure: 1. MIRU pumping equipment. �, �, ` 2. Shut down ESP. 3. Pressure test surface lines to 1800-2,000 psi (treatment pump relief valve limit). 4. Mix chemicals and pump in the following sequence: a. Open back side, pump FIW down tubing taking returns up the annulus. b. Pump 1320 gallons of pre-flush (330 gallons WAW-5206 mutual solvent blended with 990 gallons of Xylene. c. Pump 4,500 gallons of 15% HCL d. Close the 9-5/8" casing return line and bullhead the chemical pills across the perfs with 215 barrels of FIW for displacement. 5. Shut down pump and let acid soak for 6 hours. 6. RD Pumping equipment. 7. Return well to production. 8. Schedule a No-Flow test within 14 days of stable production. Attachments: 1. As-built Schematic King Salmon Platform SCHEMATIC Well # K-17 ,,, Completion: 06/30/2014 KB=100'ANN CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 MEW 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9 5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 133'8"(,2183' 9-5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' Tubing: - - 4-1/2" 12.64 IMP BTC 3.958 Surf 9,871' Casing damage 7,876'_7,86' JEWELRY DETAIL CertEd S+d 62074 No. Depth Item 1 33.7' Hanger Di 2 9,872' Bolt On Discharge e g Casirgdarege Pump(x3) 675 Series,039 9, 3 9,874' Stage,SH10000 Certert Std 62074 4 9,928' Seals 2 Motor(x2)562 Series, W 5 9,946' KMP1,340 HP 3 6 10,010' Centralizer/Anode 4 7 11,800' CIBP - -5 PERFORATION DATA 6 ' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Comment G-1 10,828' 10,846' 8,793' 8,806' 13 Open G-2 10,878' 10,907' 8,830' 8,852' 22 Open C 1-6 G-2 10,922' 10,946' 8,863' 8,881' 18 Open G-3 10,990' 11,007' 8,913' 8,926' 13 Open G-4 11,040' 11,086' 8,950' 8,984' 34 Open G-4 11,127' 11,139' 9,015' 9,024' 9 Open HB-1,2,3,4 Open G-5 11,183' 11,249' 9,057' 9,107' 50 G-6 11,318' 11,350' 9,160' 9,185' 25 Open 4101 ET: HK-1 11,419' 11,457' 9,238' 9,268' 30 Open 7 0BP*11,801Y ND HK-1 11,420' 11,460' 9,239' 9,270' 40' rigi . _?Isg: llB-S- 1D HK-2 11,482' 11,539' 9,288' 9,332' 57 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' HK-2 11,551' 11,584' 9,342' 9,374' 33 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' HK-3 11,592' 11,655' 9,374' 9,423' 63' HK-3 11,595' 11,646' 9,376' 9,416' 51' Open MI- -?1121E liBb HK-4 11,655' 11,774' 9,423' 9,517' 119' HK-5 11,856' 11,876' 9,581' 9,597' 20' SQZD '': ;,i'9 HK-6 11920 11,975' 9,631' 9,674' 55' iy- : ` 9 sig,csg Fish: FETID=12,025' 1D=12,12011,676'-Partial Bridge Plug ry (HZuEANaE_44°@x 11,688' Obstruction ESP remaining in well above CIBP Updated by:ILL 07/29/14 STATE OF ALASKA • AL/A6KA OIL AND GAS CONSERVATION COM. _,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon CI Plug Perforations EI Fracture Stimulate ❑ `n Pull Tubing E Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate El A Li Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 173-001 RECEIVED 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20248-00 JUL 2 3 1(l±5 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit/K-17 AOG CC C 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 12,120 feet Plugs measured 11,800 feet true vertical 9,787 feet Junk measured 11,676 feet Effective Depth measured 12,025 feet Packer measured N/A feet true vertical 9,713 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,038' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner Perforation depth Measured depth See Schematic feet CANNED AUG 1 0 2015 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/IMP BTC 9,871'(MD) 8,050'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10,828-11,688 Treatment descriptions including volumes used and final pressure: 330 gallons WAW-5206,990 gallons Xylene, 110 bbls 10%HCL,215 bbls FIW. Final pressure 900 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 138 115 6236 70 71 Subsequent to operation: 133 51 3565 75 70 14.Attachments(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ 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: 315-415 Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe / Title Operations Engineer ��Signature 4.. �,�_.� r a..., /ut.„`‘?f ih-on> (907)283-1329 Date 7/23/2015 L -7_ z si--/ RBDMS J!,! 2 4 2015 Form 10-404 Revised 5/2015 / Submit Original Only /2--2,--4_5----- King Salmon Platform r ii SCHEMATIC well# K-17 1lilcorp Alaska,I.IA: Completion: 06/30/2014 KB=1W MN, CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 MilIf 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9-5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 133/8"183' 9-5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' Tubing: - 4-1/2" 12.6# IMP BTC 3.958 Surf 9,871' '1 CM rig&►age 7,816-7,826 JEWELRY DETAIL CeTatSeri 612014 No. Depth Item 1 33.7' Hanger 2 9,872' Bolt-On Discharge erg darrage Pump(x3) 675 Series,039 W° 3 9,874' Stage,SH10000 Cede-[Std 612074 4 9,928' Seals 2 O_ Motor(x2)562 Series, 3 II 5 9,946' KMP1,340 HP ,_,, 6 10,010' Centralizer/Anode 4 g 7 11,800' CIBP 5 PERFORATION DATA 6 * Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt Comment G-1 10,828' 10,846' 8,793' 8,806' 13 Open G-2 10,878' 10,907' 8,830' 8,852' 22 Open = G1-6 G-2 10,922' 10,946' 8,863' 8,881' 18 Open G-3 10,990' 11,007' 8,913' 8,926' 13 Open G-4 11,040' 11,086' 8,950' 8,984' 34 Open G-4 11,127' 11,139' 9,015' 9,024' 9 Open = 113-1,2,3,4 Open G-5 11,183' 11,249' 9,057' 9,107' 50 G-6 11,318' 11,350' 9,160' 9,185' 25 Open 0 .... HK-1 11,419' 11,457' 9,238' 9,268' 30 Open 7 CIBP@11,801PNID HK-1 11,420' 11,460' 9,239' 9,270' 40' iz . ...?zig H13-5_SOW HK-2 11,482' 11,539' 9,288' 9,332' 57 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' HK-2 11,551' 11,584' 9,342' 9,374' 33 Open HK-2 11,552' 11,592' 9,342' 9,374' 40' HK-3 11,592' 11,655' 9,374' 9,423' 63' HK-3 11,595' 11,646' 9,376' 9,416' 51' Open I-iB6 HK-4 11,655' 11,774' 9,423' 9,517' 119' HK-5 11,856' 11,876' 9,581' 9,597' 20' SQZD 1:f fi '' ''�. HK-6 11920 11,975' 9,631' 9,674' 55' • /;' ` r A r ti; 1::\ 9518"csg Fish: PgfD=12.03' 11)=121211 11,676'-Partial Bridge Plug fvtaI-JIEANQE_4�@ 11,688' Obstruction ESP remaining in well above CIBP Updated by:.11.1.07/29/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 173-001 7/21/15 7/21/15 Daily Operations: 07/21/15-Tuesday Spot and rig up pumping equipment. Pressure test discharge hose at 500&2000 psi. Pump 144 bbls FIW down tubing at 2 bpm taking returns up annulus. Pump 330 gallons WAW-5206 mutual solvent mixed with 990 gallons xylene,followed by 110 bbls 10%HCL acid.Close annulus valve and begin bull heading with 215 bbls FIW at 1 bpm, max treatment pressure 1250 psi breaking down when acid reached top of hemlock formation. Final treatment pressure 900 psi. Shut down pump at 20:45,disconnect treatment lines from wellhead and secure. Place well on a 6 hour soak and turn over to production. rof Tk�n • /7: THE STATE Alaska Oil and Gas of TdAsKA Conservation Commission 333 West Seventh Avenue '16411F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS1''P Fax 907 276 7542 www aogcc.alaska.gov Dan Marlowe Operations Engineer 1 3 00I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil & Middle Kenai G Oil Pools, TBU K-17 Sundry Number: 315-415 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, Cathy P oerster Chair DATED this �7-day of July, 2015 Encl. • . RECEIVED IVED STATE OF ALASKA JUL 0 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 0(7-. . 7//5//S APPLICATION FOR SUNDRY APPROVALS A.UGCC 20 AAC 25-280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate 2(Acid)% Alter Casing ❑ Change Approved Program ❑ Plug for RedriN 0 Perforate New Pool ❑ Repel'Well ❑ Re-enter Susp Well ❑ Other: 0 2.Operator Name 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC , Exploratory ❑ Development 0 ` 173-001 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20248-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/AI Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay Unit/K-17 " 9 Property Designation(Lease Number). 10.Field/Pool(s). ADL0017594 ' McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft). Plugs(measured): Junk(measured): - 12,120 - 9,787 - 12,025 - 9,713 11,800' 11,676' Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,038' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,769' 6,820 psi 4,230 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft) Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ' See Schematic 4-1/2" 12.6#/IMP BTC 9,871' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) N/A N/A 12.Attachments: Descnption Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory 0 Stratigraphic❑ .velopment 2 N Service El 14 Estimated Date for 15 Well Status after proposed work Commencing Operations: 7/25/2015 OIL 0 l WINJ ❑ WDSP❑ Suspended ❑ 16.Verbal Approval: Date GAS ❑ WAG El GSTOLI SPLUG ❑ Commission Representative GINJ El Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Pnnted Name Dan Marlowe Title Operations Engineer �JSignature v {/—}'� 4 '^1 � owe, Phone (907)283-1329 Date 7/8/2015 -1�it DOA /Kn"La� oVV e COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i5 - 4-tr5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes 0 No Subsequent Form Required /0 q Oy APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:7-/cL-/S t' 7/3// 7.(3•/5 0 I G I INAL ,A7 /6----- Submit Form and � Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval.RBDMOr I Ip4/yplg5 Well Work Plan Well: K-17 Elilcorp Alaska.LL Date:07/08/2015 Well Name: K-17 API Number: 50-733-20248-00 Current Status: ESP Lifted Producer Leg: Leg#1 NE Corner Estimated Start Date: July 25, 2015 Rig: N/A Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 173-001 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 700 psi @ 8,700' TVD ESP Intake Gauge Maximum Expected BHP: 4314 psi @ 8,700' TVD (ESP intake Gauge). Well SIBP of 2314psi plus 2000 psi pump pressure. Max. Anticipated Surface Pressure: 1800-2,000 psi treatment pump pressure limit Well Summary The K-17 is an oil well producer which is currently on ESP artificial lift. Total fluid production from this well has decreased substantially since the June 2014 work over. This decrease is believed to have been caused by scale formation in the well bore and perforation tunnels. Well Objective Hilcorp plans to pump an acid soak down the production tubing and across the perforations to clean up any scale deposition. Procedure: 1. MIRU pumping equipment. 2. Shut down ESP. 3. Pressure test surface lines to 1800-2,000 psi (treatment pump relief valve limit). 4. Mix chemicals and pump in the following sequence: a. Open back side, pump FIW down tubing taking returns up the annulus. b. Pump 1320 gallons of pre-flush (330 gallons WAW-5206 mutual solvent blended with 990 gallons of Xylene. c. Pump 4,500 gallons of 10% HCL tot - d. Close the 9-5/8" casing return line and bullhead the chemical pills across the perfs with 215 barrels of FIW for displacement. 5. Shut down pump and let gsicLsaak for 6 hours. 6. RD Pumping equipment. 7. Return well to production. 8. Schedule a No-Flow test within 14 days of stable production. Attachments: 1. As-built Schematic King Salmon Platform SCHEMATIC Well# K-17 "��,,,qke,,,, Completion: 06/30/2014 KB=WY ANH, CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9-5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 14 ' 133' a 2183' 9-5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' Tubing: 4-1/2" 12.6# IMP BTC 3.958 Surf 9,871' Buz 7- � � CbEilaik 7,816 7,8266'1, I- JEWELRY DETAIL No. Depth Item 9 133.7' Hanger Isi. tf L �?J' 2 9,872' Bolt-On Discharge ( •�gleek ( Pump(x3) 675 Series,039 4. �; noes ?(' 3 9,874' Stage,SH10000 ? 15'i S 4 _ 9,928' Seals 2 Motor(x2)562 Series, 1111 3 5 9,946' KMP1,340 HP 6 10,010' Centralizer/Anode 4 7 11,800' CIBP um, 5 PERFORATION DATA 6 Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt Comment G-1 10,828' 10,846' 8,793' 8,806' 13 Open G-2 10,878' 10,907' 8,830' 8,852' 22 Open = G1-6 G-2 10,922' 10,946' 8,863' 8,881' 18 Open G-3 10,990' 11,007' 8,913' 8,926' 13 Open G-4 11,040' 11,086' 8,950' 8,984' 34 Open G-4 11,127' 11,139' 9,015' 9,024' 9 Open IK1,2,3,4 Open G-5 11,183' 11,249' 9,057' 9,107' 50 G-6 11,318' 11,350' 9,160' 9,185' 25 Open gill = HK-1 11,419' 11,457' 9,238' 9,268' 30 Open 7 CIBP@11,800'1 iI HK-1 11,420' 11,460' 9,239' 9,270' 40' lgg-SD HK-2 11,482' 11,539' 9,288' 9,332' 57 Open HK-2 11,482' 11,540' 9,288' 9,333' 58' HK-2 11,551' 11,584' 9,342' 9,374' 33 Open 1). ? HK-2 11,552' 11,592' 9,342' 9,374' 40' HK-3 11,592' 11,655' 9,374' 9,423' 63' HK-3 11,595' 11,646' 9,376' 9,416' 51' Open I-11BC HK-4 11,655' 11,774' 9,423' 9,517' 119' 4` HK-5 11,856' 11,876' 9,581' 9,597' 20' SCtZD 4 + 'µrt ' {t,grr, HK-6 11920 11,975' 9,631' 9,674' 55' 11.1:1!t't "V,, ' ' ,f-7'4'.%:1".;-;•"31M�u(ALF �i. 958"csg Fish: P6iD=12,(125 ID=12121 11,676'-Partial Bridge Plug MuHiL MW-44 @MO11,688' Obstruction ESP remaining in well above CIBP Updated by:JLL 07/29/14 Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Monday,July 13, 2015 1:56 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA);Juanita Lovett;Trudi Hallett; Ted Kramer Subject: RE: K-17 (PTD 173-001) Acid Soak. Attachments: 10-404 - King Salmon K-17 -- 2014-07-30 Submitted.pdf Guy You are correct we did pass a casing test during the last work over. We had two leak points identified that we squeezed with cement-See attached summary for work completed between June 11-24`h, 2014. Final casing test was after final cement squeeze right before drilling out the EZSV on June 24th at 9251'to 1500 psig for 30 minutes. Let me know if you have any additional questions Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe©hilcorp.com Hilcorp A Company Built on Energy From: Schwartz, Guy L(DOA) [mailto:guv.schwartz@alaska.gov] Sent: July 13, 2015 1:45 PM To: Dan Marlowe Cc: Bettis, Patricia K (DOA) Subject: K-17 (PTD 173-001) Acid Soak. Dan, Can you elaborate on the casing leaks seen on the schematic(7816-7826' and 9098'). I thought this well passed a pressure test during the last workover. Please verify the casing is competent and can hold the proposed injection pressure during the acid stim. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 THp](�F STATE 4 GOVERNOR SEAN PARNFIA, Mr. Stan Golis Operations Manager — Cl Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Trading Bay Unit K-17 PTD 1730010 Dear Mr. Golis: September 16, 2014 333 \Nest Sevenlh Avenue Anchorage, Alaska 99501-3572 Main: 907-279.1,"- , On July 10, 2014 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay Unit K-17 located on the King Salmon Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail- safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to Trading Bay Unit K-17. The well had been shut in for approximately 24 hours leading up to the test. The well was monitored while shut in for an additional 3 hours with no change in the pressure (<1 psi). The well's tubing and tubing -casing annulus were then bled to atmosphere with an initial gas rate of 750 scf/hour decreasing to zero flow in less than 3 minutes; no liquid flow was observed meeting the criteria for a no -flow status. The subsurface safety valve must be returned to service if Trading Bay Unit K-17 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon Platform. Sincerely, �1�t�lfG� � James B. Regg / Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 21 Other 0 lrstall ESP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ 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: Name: Hilcorp Alaska, LLC Development Exploratory ❑ Stratigraphic❑ Service ❑ 173-001 3. Address: 3800 Centerpoint Drive, suite 1400 6. API Number: Anchorage, AK 99503 50-733-20248-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 Trading Bay Unit / K-17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 12,120 feet Plugs measured 11,800 RECEIVE true vertical 9,787 feet Junk measured 11,676' feet JUL 3 0 2014 Effective Depth measured 12,025 feet Packer measured N/A feet true vertical 9,713 feet true vertical N/A feet 10G(vse1%� vv Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,037' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,767' 6,820 psi 4,230 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / IMP BTC 9,871' (MD) 8,050' (TVD) Packers and SSSV (type, measured and true vertical depth) Pkr: N/A SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9,098'- Squeezed lower leak with 16 bbls. of class G cement with a final squeeze pressure of 850 PSIG. Pulled up hole and squeezed upper leak from 7,816' - 7,826' with 15 bbls. of class G cement with a final squeeze pressure of 1,400 psi. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 235 0 Subsequent to operation: 100 151 9,774 80 71 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ DevelopmentR] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSPL❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1314-179 Contact Ted Kramer Email tkramer(a hilcorg.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature Phone (907) 777-8420 Date 7/30/2014 Form 10-4U4 Kevised 1MU11 I Z M _00,r►� QubBmC;nS JUnly UL J 12 King Salmon Platform SCHEMATIC Well #K-17 Ililrnrp Alnekn, 1.,.1: Completion: 06/30/2014 KB=100' ANISL, 133/8' X183' "1 Casing leak 7,819 -7,829 Coming leak 9,o° 11,2,3,4 GBP@11,800' MD M5 -SW 9-W' csg PB1D=1ZC25 TD=u,l' Nlex FULEMIGLE-44' @3800' SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9-5/8 40.0 RS -95 BTC 8.835 Surf 7,031' 9-5/8 43.5 RS -95 BTC 8.755 7,031' 12,096' Tubing: 8,881' 18 Open G-3 10,990' 4-1/2" 12.6# IMP BTC 3.958 Surf 9,871' JEWELRY DETAIL No. Depth Item 1 33.7' Hanger 2 9,872' Bolt -On Discharge 3 1 9,874' Pump (x3) 675 Series, 039 Stage, SH10000 4 9,928' Seals 5 9,946' Motor (x2) 562 Series, KMP1, 340 HP 6 10,010' Centralizer/Anode 7 1 11,800' 1 CIBP PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Comment G-1 10,828' 10,846' 8,793' 8,806' 13 Open G-2 10,878' 10,907' 8,830' 8,852' 22 Open G-2 10,922' 10,946' 8,863' 8,881' 18 Open G-3 10,990' 11,007' 8,913' 8,926' 13 Open G-4 11,040' 11,086' 8,950' 8,984' 34 Open G-4 11,127' 11,139' 9,015' 9,024' 9 Open G-5 11,183' 11,249' 9,057' 9,107' 50 Open G-6 11,318' 11,350' 9,160' 9,185' 25 Open HK -1 11,419' 11,457' 9,238' 9,268' 30 Open HK -1 11,420' 11,460' 9,239' 9,270' 40' HK -2 11,482' 11,539' 9,288' 9,332' 57 Open HK -2 11,482' 11,540' 9,288' 9,333' 58' HK -2 11,551' 11,584' 9,342' 9,374' 33 Open HK -2 11,552' 11,592' 9,342' 9,374' 40' HK -3 11,592' 11,655' 9,374' 9,423' 63' HK -3 11,595' 11,646' 9,376' 9,416' 51' Open HK -4 11,655' 11,774' 9,423' 9,517' 119' HK -5 11,856' 11,876' 9,581' 9,597' 20' SQZD HK -6 11920 11,975' 9,631' 9,674' 55' Fish: 11,676' - Partial Bridge Plug 11,688' - Obstruction ESP remaining in well above CIBP Updated by: JLL 07/29/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 05/04/14 - Sunday Rigging up. 05/05/14 - Monday Rigging up. 05/06/14-Tuesday RECEIVED VERBAL APROVALTO BEGIN TESTING BOPE FROM JIM HILL WITH AOGCC @ 08:57 HRS WHILE ON WEATHER HOLD DUE TO FOG. JIM HILL WITH AOGCC ARRIVED ON PLATFORM @ 11:30 HRS. TEST ALL BOPE TO 250 LOW & 2500 HIGH HOLDING ALL TEST ON CHART FOR 5 MINUTES. ALL TEST WITNESSED BY JIM HILL WITH AOGCC. TEST GAS DETECTION STATIONS AROUND RIG, PERFORM KOOMEY DRAW DOWN & TEST NITROGEN BOTTLES ON KOOMEY. REMOVE TEST ASSEMBLY & L/D SAME. INSTALL WEAR BUSHING & PREPARE TO P/U BHA #1, SLM & CALIPER BHA #1. P/U OVERSHOT DRESSED WITH 4-1/2" BASKET GRAPPLE, BUMPER JARS, OIL JARS, & (6) 4-3/4" DRILL COLLARS, SLM. P/U & TIH WITH (30) 3- 1/2" 12.95# JOINTS OF TUBING TO 1,195'. 05/07/14 - Wednesday CONTINUE P/U 3-1/2" 12.95# TUBING & TIH F/1,195' TO 2,472'. INSTALL HALLS HEAD RUBBER & ENGAGE FISH. BOTTOM OUT @ 2,519' WITH 20K DOWN. P/U ON TUBING & HAD NO OVERPULL. HOOK UP PUMP LINES & REVERSE CIRCULATE ACROSS FISH TOP. SET 20K DOWN ON FISH, P/U & HAD NO OVER PULL. ATTEMPT TO POOH, TONGS NOT BITING ON TUBING SCARRING UP TOOL JOINTS. POOH WITH 3-1/2" TUBING, RACK BHA IN DERRICK. BREAK DOWN OVER SHOT & SHUCK WIRE LINE SETTING TOOL. POORBOY EQUILIZING SHIFTING TOOL FOR WRP BRIDGE PLUG ARRIVED ON PLATFORM @ 2000 HRS. TIH WITH JARS, D.C.'S, & 3-1/2" 12.95# TUBING. ENGAGE FISH @ 2,519' SETTING DOWN 20K - 30K REPEATLY TRYING TO SHIFT EQUALIZING SLEEVE. POOH WITH 3-1/2" TUBING & BHA FROM 2,519' TO SURFACE. TATTLE TAIL PINS INSIDE POORBOY SHIFTER STILL INTACT INDICATING WE WERE NOT OVER FISH. HAD MARKS ON SIDE OF W-LEG INDICATING POSSIBLY ON SIDE OF WRP BRIDGE PLUG. MODIFY & WELD CENTRALIZER BLADES ON OUTSIDE OF POORBOY SHIFTER. TIH WITH POORBOY SHIFTER BHA & 3-1/2" TUBING, INSTALL HALLS HEAD RUBBER & PREPARING TO ENGAGE FISH @ 2,519' REVERSE CIRCULATING TO SHIFT EQUALIZING SLEEVE ON WRP BRIDGE PLUG. 05/08/14 - Thursday SERVICE RIG & EQUIPMENT. R/U CIRCULATING LINES, ENGAGE FISH @ 2,519', SET 20K DOWN ATTEMPTING TO SHIFT EQUALIZING SLEEVE. REVERSE CIRCULATE 2 BPM @ 50 PSI OFF BOTTOM, STACK 20K OF WT. ON BOTTOM & HAD 100 PSI PRESSURE INCREASE. REVERSE CIRCULATE 2 TUBING VOLUMES. R/D CIRCULATING LINES & PREPARE TO POOH. POOH WITH 36 STANDS OF 3-1/2" 12.95# TUBING. RACK BACK DRILL COLLARS & L/D JARS. TATTLE TAIL PINS INSIDE POORBOY SHIFTING TOOL STILL INTACT. HAD THREE DISTINCTIVE MARKS ON W-LEG ENTRY GUIDE ( MARKS MEASURE 3.75" O.D.). DISCUSS WITH WEATHERFORD & MARKS INDICATE THAT AUTO "J" STYLE FISHING NECK WAS RUN WITH WRP BRIDGE PLUG AND NOT ORIGINAL COLLET STYLE. LOCATE WEATHERFORD AUTO "J" PULLING TOOL, PULLING TOOL TO BE IN STATE & AT HELIPORT ON 5/9/14 APPROXIMATELY 1200 HRS. PERFORM HOUSEKEEPING & MAINTENANCE WHILE WAITING ON WEATHERFORD RETRIEVING TOOLS. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 05/09/14 - Friday PERFORM HOUSEKEEPING WHILE WAITING ON AUTO J RETRIEVING TOOL. P/U 5.75" WEATHERFORD AUTO J RETRIEVAL TOOL (3.75" I.D.) WITH 8.20" CENTRALIZED PUP JOINT. TIH WITH BHA & 3-1/2" 12.95# TUBING TO FISH TOP @ 2,519'. INSTALL TIW & HALLS HEAD WITH STRIPPING RUBBER. ATTEMPT TO LATCH ONTO WRP BRIDGE PLUG REPEATLY BY SETTING 30K DOWN, PUTTING RIGHT HAND TURNS, ATTEMPTING TO CIRCULATE & WASH WITH 0 PSI @ 2 BPM WITH NO SUCCESS. SPUD ON PLUG WITH 30K DOWN ATTEMPTING TO LATCH PLUG WITH NO SUCCESS. PREPARE TO POOH. POOH WITH 3-1/2" TUBING FROM 2,519' TO SURFACE. TIH WITH AUTO J ASSEMBLY BHA & 3-1/2" 12.95# TUBING TO TOP OF FISH AT 2,519'. ESTABLISH P/U WT = 34K, S/0 WT = 30K. ENGAGE FISH WITH 20K DOWN. P/U & HAD 2K OVER PULL. SPUD DOWN ON FISH SEVERAL TIMES TO ENSURE A GOOD J LATCH. P/U 15' AND DRAG PLUG UP HOLE. HAD GAS CUT FLUID RETURNS ON TUBING. REVERSE CIRCULATE 2 TUBING VOLUMES DISPLACING GAS FROM TUBING WITH FIW. MONITOR WELL FOR 15 MINUTES. (WELL STATIC). POOH SLOWLY WITH 3-1/2" TUBING. PLUG DRAGGING UP HOLE 2K - 4K OVER STRING WT. HAD FULL RECOVERY OF WRP BRIDGE PLUG, L/D SAME. SLM, CALIPER, & P/U BHA #4. 05/10/14 - Saturday TIH WITH 3-1/2" TUBING FROM DERRICK TO 2,519'. SLM, P/U, & TIH WITH 147 JOINTS OF 3-1/2" 12.95# TUBING. TAG EZSV @ 6,992'. R/U POWER SWIVEL, INSTALL HALLS HEAD ADAPTOR FLANGE WITH STRIPPER RUBBER. PUMP 175 BBLS OF DIRTY 9.2 PPG FLUID FROM RIG TANKS TO TRADING BAY. CLEAN RIG TANKS & FILL WITH CLEAN FIW. DISPLACE K-17 WITH 8.5 PPG FIW SENDING RETURNS TO TRADING BAY. DISPLACE TOTAL OF 490 BBLS FROM K-17 WELL BORE. TOTAL SENT TO TRADING BAY = 665 BBLS. MILL EZSV FROM 6,992' TO 6,994.5'. ROTATING 80 RPM, 4K-6K FT/LBS TORQUE, PUMPING 3 BPM @ 250 PSI, CIRCULATING BOTTOMS UP & CHECKING FOR FLOW EVERY 6" OF DRILLED PLUG. PUSH PLUG DOWN HOLE FROM 6,994.5' TO 7,027'. TAG SECOND EZSV. MILL 6" OF REMAINING PLUG. REVERSE CIRCULATING @ 3 BPM & 250 PSI, PACKING OFF SURFACE LINES WITH COMPOSITE PLUG DEBRIS. 05/11/14 - Sunday REVERSE CIRCULATE 2 TUBING VOLUMES AT 3 BPM & 250 PSI. R/D POWER SWIVEL & REMOVE HALLS HEAD ADAPTOR FLANGE. PREPARE TO POOH, POOH WITH 3-1/2" TUBING FROM 7,027' TO SURFACE, RACK BHA IN DERRICK, L/D 8.5" MILL. P/U 8.125" PACKER SHOE WITH TOP BUSHING, TIH WITH BUMPER/OIL JARS, (6) 4-3/4" DRILL COLLARS, ACCELERATOR JAR, & X-O. TIH WITH 3-1/2" 12.95# TUBING TO 7,002'. R/U POWER SWIVEL & INSTALL HALLS HEAD ADAPTOR FLANGE WITH STRIPPER RUBBER. BURN OVER EZSV F/7,027' TO 7,030, REVERSE CIRCULATING 3 BPM @ 300 PSI, 4K-6K FT/LBS OF TORQUE WITH 90 RPM. CIRCULATE BOTTOMS UP EVERY 6" DRILLED & CHECK FOR FLOW. BEGAN RECEIVING MAGNETIZED METAL AFTER MILLING 18" OF PLUG. AFTER MILLING 36" OF PLUG CIRCULATION WAS LOST. P/U FROM 7,030' TO 7,025'. CLOSE HYDRIL, HAD 250 PSI ON TUBING & 0 PSI ON CASING. BEGIN REVERSE CIRCULATING GAS KICK FROM WELL, RECEIVING GAS & OIL RETURNS. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 05/12/14 - Monday REVERSE CIRCULATE 3 BOTTOMS UP (186 BBLS). PUMP 240 BBLS OF NON PRODUCED FLUID TO TRADING BAY FROM RIG TANK, TOTAL OF APPROXIMAYELY 60 BBLS OF OIL MIXED WITH NON PRODUCED FLUID. CLEAN RIG TANKS & FILL WITH FIW. POOH WITH 23 STANDS OF 3-1/2" TUBING FROM 7,025' TO 5,564'. BEGAN GETTING OIL RETURNS OUT OF TUBING. REVERSE CIRCULATE 1 SURFACE TO SURFACE VOLUME (450 BBLS) SENDING ALL RETURNS TO TRADING BAY. POOH WITH 3- 1/2" TUBING FROM 5,564' TO 1,016'. REVERSE CIRCULATE OIL FROM TUBING, MONITOR WELL FOR FLOW TO POOH WITH BHA. POOH WITH 3-1/2" TUBING & BHA, L/D 8-1/8" PACKER MILL ASSEMBLY, P/U BHA #6, 8-1/8" SHORT CATCH OVERSHOT DRESSED WITH 6.5" GRAPPLE. TIH WITH OIL/BUMPER JARS, (6) 4-3/4" DRILL COLLARS, & ACCELERATOR JARS. TIH WITH 9 STANDS OF 3-1/2" TUBING TO 821'. R/U CIRCULATING LINES & REVERSE CIRCULATE OIL FROM TUBING, CHANGE OUT MCCOY TONGS & R/U FOSTER TONGS WHILE CIRCULATING. TIH WITH 3-1/2" TUBING TO 7,016'. SLM, P/U, & TIH, PICKING UP PIPE FROM CATWALK. TAG PLUG @ 7,716'. P/U POWER SWIVEL, INSTALL HALLS HEAD ADAPTOR WITH STRIPPER RUBBER. TAG PLUG WITH 15K DOWN AT 7,716', PUSH PLUG DOWN HOLE TO 7,736'. ATTEMPT TO LATCH PLUG SETTING 15K DOWN WITH RIGHT HAND TORQUE. PUMP PRESSURE RISING WHEN OVER TOP OF FISH THEN FALLING OFF WHEN P/U OFF OF FISH. ATTEMPT TO REVERSE CIRCULATE HOLE CLEAN. PUMPING 2.5 BPM @ 140 PSI. UNABLE TO ESTABLISH RETURNS. TOTAL FLUID LOST LAST 24 HRS = 416 BBLS. L/D POWER SWIVEL & PREPARE TO POOH. 05/13/14-Tuesday SERVICE RIG & EQUIPMENT, POOH WITH 3-1/2" 12.95# TUBING FROM 7,736' TO SURFACE WITH A WET STRING. Finish POOH. Retrieved plug #2 in overshot. Break out and lay down overshot assembly. Remove plug from overshot. Retrieve wear bushing. PU MU 8 1/4" OD short catch overshot with 6" grapple, bumper, oil, (6) 4 3/4 drill collars, intensifier, 3 1/2 PH-6 workstring. TIH PU Halliburton storm packer. MU to workstring. TIH 100' and set packer in 9 5/8 casing and hang off workstring. Release and POOH. PU MU test plug. Test BOPE 250 psi low / 3,000 psi high. Witness of test waived by Jim Regg, AOGCC. Had one leak on quick connect on annular BOP. Replaced quick connect. Remove Test plug. TIH and release storm packer, POOH with packer. Break out and lay down packer. PU power swivel, TIH to 7,736' and latch onto plug #3. 05/14/14 - Wednesday RU power swivel, install stripper rubber. RIH and tag plug #3 at 7,736'. Pushed downhole 10'. Work 8 1/4 shortcatch overshot to engage plug for 1 1/2 hours. Remove stripper rubber on single. POOH. Fill hole with 173 bbls. FIW. OOH with workstring. Stand back drill collars and jars. No recovery. No marks inside grapple. Cutlip had marks only. Continue to have trouble installing wear bushing through annular rubber. Install wear bushing. PU MU 8 1/2" OD x 7" ID flat bottom shoe with non-rotating cable grab sleeve 6" long, 8" washpipe extension, top bushing, jars, drill collars. TIH to 7,744' tagged plug 2' higher. PU power swivel. Initially plug was spinning but eventually locked up. Began milling with 2-3K weight. Made 14" as of report time. Torque at 5K, total fluid loss 216 bbls so far. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations:. 05/15/14 - Thursday Continue milling on plug #3 at 7,744'. Made 15" milling on plug. Pumping 3.5 bpm with approximately 5K torque. Depth 7,745'. Torque smoothed out and no progress made for 2 hours. RD power swivel. POOH. Recovered bottom nut and mandrel of EZSV plug #3. Break out non-rotating cable grab shoe, extension, top bushing. Bottom nut wedged in bottom of shoe, mandrel caught in cables. PU MU 3 1/2 PH-6 mule shoe and workstring. TIH to 7,744'. Displace hole with FIW to Trading Bay, total of 750 bbls. RU Eline unit with downhole camera. Currently TIH with Eline, test camera at 200', and every 2000' while TIH. 05/16/14 - Friday Continue to RIH with downhole camera to 7,746'. Take video of 8-10 long mandrel, slip pieces, capillary line and ESP cable sheathing unwound. POOH RD/LD Eline. Fill hole with 28 bbls. POOH with 3 1/2 PH-6 workstring and mule shoe. Finish POOH with workstring. PU MU 8 1/4 x 5 7/8 short catch overshot with 4" grapple, bumper, oil (6) 4 3/4 drill collars, intensifier and work string to 7,746". PU power swivel. Work to engage plug mandrel. No real indications. POOH. OOH with short catch overshot. No recovery. Marks on end of overshot showed mandrel did not enter grapple. PU overshot and making up now. 05/17/14 - Saturday PU MU Modified cutlip bevel on 8 1/4 short catch overshot, bumper, oil, (6) drill collars, intensifier work string to 7,746'. PU power swivel. Work to engage mandrel stub. RD power swivel. POOH with overshot assembly. Recovered 10" plug #3 mandrel stub and (2) pieces of composite plug slips. PU MU Bulldog scrub grab spear, stop sub with 8 1/2" OD stop ring with 4 holes, bumper, oil, (6) drill collars, intensifier, 3 1/2 PH-6 work string TIH to 7,746' top of ESP cable. Work scrub grab spear into top of ESP cable. Top of cable tight at first, then worked past 5' and torqued up cable onto spear. Torque was enough to stall out swivel at 6K torque. Had 5K overpull once into cable. New top of fish at 7,751'. RD power swivel and POOH. At top of drill collars now. Total fluid loss to well 156 bbls. 05/18/14 - Sunday Finish POOH with scrub grab spear, jars, (6) drill collars. No recovery. TIH with same assembly. Scrub grab spear, bumper, oil, (6) drill collars, intensifier and 3 1/2 PH-6 work string. TIH to 7,751'. Install stripper head, PU power swivel. PU 85K/SO 75K. Rotate and set various weights torqueing up to 7K. Had 15K overpull. Pull with power swivel connected while turning to the right with torque for 4 joints. Still have overpull and 5-6K torque. Fill hole with 18 bbls FIW. POOH with scrub grab spear assembly. Fill hole with 72 bbls while POOH. Recovered 124' ESP cable. Large piece and several small pieces of EZSV plug/composite plug caught in cable ball. Laid out cable and removed from spear. TIH with 3 1/2 mule shoe, 3 1/2 PH-6 work string to 7,837'. Tagged obstruction. Stopped at 7,837'. RU Water flood and pumped 540 bbls. to Trading Bay to clean up well for downhole camera run. RU Eline and downhole camera. RIH to 7,800' wireline measurements. At 5,400' picture OK. At 7,800' not visible. RU pump in sub and pump 1 bbl FIW from Water Flood to clear up visibility. Current activity pumping fresh FIW. Sent in BOPE Witness request to AOGCC, Sunday 5/18/2014, for BOPE test on Tuesday 5/20/2014. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 05/19/14 - Monday Continue RIH with downhole camera to 7,800' WLM. Fluid not clear. Pump at 1 bpm for 30 minutes. Wait 45 minutes. Fluid cleared up. Tool video and POOH. Showed ESP cable only no junk. Cable is looped over on top. POOH with Eline. RD. POOH with 3 1/2 mule shoe, 3 1/2 PH-6 work string. Fill hole with 138 bbls. PU MU scrub grab spear, jars, (6) 4 3/4 drill collars, work string. TIH to 7,837'. Begin working spear to engage ESP cable. Worked up to 7K torque. It would torque up and release, then we could slack off 1' and it would torque up again and have over pull of 25-35K. we did this several times all in the same spot. Made 5'. POOH. OOH with spear assembly. Pumped 88 bbls. Recovered approximately 5' of wadded up cable components. Had strong scarring on bottom of scrub grab spear. Removed cable from spear. TIH with 3 1/2 mule shoe, 3 1/2 PH-6 work string to 7,842'. Currently Water Flood is pumping FIW to Trading Bay. Rigging up down hole camera. 05/20/14-Tuesday Continue to pump well fluids to Trading Bay. Pumped total of 295 bbls FIW. Shut down pumping to Trading Bay. RIH with Eline/down hole camera to 7,800' WLM. Take video. Mule shoe overtop of tubing. Move work string up hole 3'. Take new video. Showed 4 1/2 tubing stub looking up with ESP cable approximately 2-3' below. POOH with Eline. RD Eline equipment. POOH with 3 1/2 mule shoe and work string. Fill hole with 25 bbls FIW before POOH. Break out mule shoe. Prepare for BOPE test. Witness waived by Jim Regg AOGCC on 5/19/14. Test BOPE 250 low/ 300 high. Hub clamp on wellhead leaked. Tightened and retested good. Heated up annular rubber to get wear bushing through. Set wear bushing. Cut and slip drill line to bad spot at 48 raps on drum. PU MU 8 1/8" OD overshot dressed with 4 1/2" grapple. Guide is wavy bottom shoe with 4 1/2 dress off pads inside. 4 3/4 bumper jars, 4 3/4 oil jars, (6) 4 3/ drill collars, 4 3/4 intensifier, crossover to 3 1/2 PH-6 work string. TIH to 7,851'. Currently on bottom and picking up power swivel. 05/21/14 - Wednesday TIH with 8 1/8" overshot to 7,851'. Dress off top of 4 1/2" tubing, engage with 8 1/8" overshot and jar. Jar for 7 1/2 hours with no movement. Release overshot and POOH. RD power swivel, POOH. Fill hole while tripping, total of 38 bbls FIW. Break out overshot and lay down. PU MU 8 1/2" flat bottom mill, 4 3/4" bumper, oil jars, (6) 4 3/4" drill collars, 4 3/4" intensifier, 3 1/2" PH-6 12.95 2 3/4" ID work string. Fill hole with 30 bbls FIW. TIH to 7,851' mill 14" of 4 1/2" tubing top to prepare for wireline. RU power swivel and mill 14" 4 1/2" tubing top. RD power swivel and POOH. Currently POOH with 8 1/2" mill BHA. 05/22/14 - Thursday Finish POOH with 8 1/2" Mill assembly. Break out mill and PU MU 8 1/8" overshot with 4 1/2" grapple. TIH to 7,841', could not get over top of 4 1/2" tubing. PU Power swivel and rotate over top of tubing and engage. Pull overpull to set grapple. RU E-line with free point indicator. TIH with 19/16" freepoint tool. Tool sticking going in hole. Made it to 2,000'. POOH. Removed freepoint tool and RIH with 13/8" sinker bars. TIH to 7,800' WLM. Could not get into top of 4 1/2" Tubing. Pulled 10K overpull. Work into top of tubing 3', sinker bars getting stuck. Over pull of 1300 ft. lbs. Attempt to pump clear, no luck. POOH. Order slick line unit and tools. Waiting on slick line unit and personnel. RU slick line and RIH with 2" magnet to 7,836'. POOH recovered small metal filings. PU 2 1/4" bailer. TIH to 7,836'. Worked bailer, made approximately 2'. POOH. No recovery. Had one new mark on bottom. Currently TIH with 2" LIB. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 05/23/14 - Friday TIH with bailer on slickline to 7,837'. POOH no recovery. TIH with 2 1/8" OD LIB. POOH had gash on one side of bottom. Did not give any clear indication of what it was. Order out downhole camera. RD slickline. RU E-line. MU TIH with Expro downhole camera on E-line to 7,800'. Pumped 143 bbls FIW to Trading Bay to clear up fluid. Took video of top of 4 1/2" tubing. Showed top smeared over with jagged edges intruding into ID of tubing top obstructing entry into 4 1/2" tubing. POOH. RD E-line. RU slickline. TIH with 1.75 swage to 7,837'. Attempt to swage out top of 4 1/2" tubing. Tool sticking. POOH. TIH with 2.58 blind box. Attempt to open up top of 4 1/2" tubing. No luck. POOH. RD slickline. RU power swivel to release 8 1/8" overshot. RD power swivel. POOH. Fill hole with30 bbls FIW. Break out overshot. PU 8 1/2" flat bottom mill. Reused previous mill in hopes it will mill smoother top on 4 1/2" tubing. TIH. Fill hole with 20 bbls FIW. RU swivel. Currently milling tubing top. 05/24/14 - Saturday TIH to 7,841' top of 4 1/2" tubing with 8 1/2" Od mill. Milled 1' of tubing with light weight. Circulated 3 tubing volumes reversing. POOH with 8 1/2" mill assembly. PU MU 8 1/8" OD overshot dressed with 4 1/2" grapple, 6 1/4" OD drilling jar, crossover to 3 1/2" PH-6 work string. TIH to 7,841' and engage tubing with power swivel. PU 10' pup joint and latch onto 4 1/2" tubing. RU E-line and downhole camera. RIH with downhole camera and eline to 7,800' WLM. Pumped 87 bbls FIW to Trading Bay to clear up fluid. Took video of fish top. Could only see ball of ESP cable sheath even with top of 4 1/2" tubing. POOH with camera. PU power swivel and released 8 1/8" overshot from tubing. TIH with eline/camera. Took video of top of tubing. Showed ball of ESP cable even with top of clean milled tubing top. POOH with camera. RD Eline. Engaged overshot onto 4 1/2" tubing. RU slickline. TIH with 1.75" OD swage. TIH to 7,833' slick line measurements. Worked swage and punched through obstruction ball. POOH. TIH with 2.30" OD swage. TIH to 7,833' and punched through obstruction ball and TIH to 11,722'. Currently POOH and will run 2.50" swage as gage run for the freepoint tool and Eline tubing cutters. Will notify AOGCC today of test on Tuesday. 05/25/14 - Sunday Continue to work with slickline swage 2.30" OD. TIH to 7,837' and knock cable pieces obstruction loose and chase down hole to 11,722'. POOH. TIH with 2.50 swage to 11,722'. Pull up hole to 7,837' and work swage through top of 4 1/2 tubing several times. POOH. RD slickline. RU Eline unit. Attempt to TIH with freepoint indicator. Too tight made it to 1,600'. POOH added weight bars and adjusted bow springs. TIH to 3,000' still very slow and tight. POOH. PU 2.500 RTC cutter #1. TIH to 11,675' Eline measurements. 23' below collar on bottom joint of tubing. Fire cutter with 15K overpull. Lost 1500 lbs. No indication of cut. POOH. PU RTC cutter #2 TIH to 11,668' and make cut with 20K overpull. PU on workstring, still showed not parted. POOH with Eline. Worked pipe and jar lightly with pump on pressure to 800 psi and parted tubing. Tubing up weight 162. PU 3'. Distance between CCL and cutter would not allow CCL to pass through 3' cut gap so TIH with CCL tool only. Observe cut gap at 11,672'. POOH with CCL. This is the lower cut RCT #1. TIH with 2 1/8" OD jet cutter to fire in cut gap to damage or sever ESP cable. TIH can only get down to 11,670'. Working jet cutter now to place in 3' tubing cut gap. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 05/26/14 - Monday TIH with jet cutter to 11,673' Eline measurements. Fired jet cutter in 3' cut gap. POOH. RD Eline. POOH with 4 1/2" tubing and ESP cable. Up weight 32K over string weight. Currently at first joint of tubing attaching cable to hydraulic spooler/reel. Had approximately 5' of 4 1/2" tubing above coupling and tubing clamp with ESP cable wrapped around it. Continue POOH spooling ESP cable laying down 4 1/2" tubing in singles. Recovered 123 joints and one piece 5' of 4 1/2" tubing 3,869'. Approximately 3,871' ESP cable, (3) GLM's, (6) 4 1/2" pup joints. Left parts of 4" tubing clamps in hole. RD cable spooling equipment. RCT cut was approximately 60%. PU MU 8 1/8" OD overshot, 6 1/4" OD drilling jars, (10) 4 3/4" OD drill collars, 6 1/4" OD intensifier, crossover to 3 1/2" PH-6 work string. TIH. At 37 stands in, getting oil returns through tubing. RU pump and circulate BU. Currently TIH. Due for BOPE test today. No response from AOGCC on test waived yet. Sent email to Jim Regg. 05/27/14-Tuesday Continue TIH with 8 1/8" overshot and jarring assembly. TIH to 7,830', begin picking up singles taking tally and running rabbit. 364 joints. TIH to 11,665', PU power swivel and begin milling/washing down. Showing 5K torque pumping at 3 bpm. Obstruction holding weight. 4-5K. Mill wash down to 11,687' could not make any more progress. Circulate BU 85 bbls. RD power swivel. RU Eline/downhole camera. TIH to 11,641' WLM, pumped 305 bbls of FIW to Trading Bay, take video of obstruction. Found tubing clamp pieces crammed inside of overshot. POOH with camera. RD Eline. New crew change. POOH with 8 1/8" overshot/jar assembly. Will conduct BOPE test when out of hole. Jim Regg, AOGCC granted a one day extension of BOPE test via e-mail on 5/27/14. Witness of test was also waived by Jim Regg, AOGCC. 05/28/14 - Wednesday Finish POOH with 8 1/8" overshot, jars, drill collar assembly. Filled well with 155 bbls FIW. Break out overshot, extension and drilling jars. Clean out metal debris. Recovered 10 lbs of milled up tubing clamps in overshot and extension. Perform BOPE test 250 low / 3000 high. Witness waived by AOGCC Jim Regg. Lay out test plug and test joint. Work to get wear bushing installed. Used hotsy to warm up annular rubber. Installed wear bushing. PU MU 8 1/2" OD flat bottom shoe with non-rotating cable sleeve, 8 1/8" OD bushing with flapper valve, 8 1/8" OD washpipe extension, 8 1/8" OD top bushing, 6 1/4" OD drilling jars, (10) 4 3/4" drill collars, 6 1/4" OD intensifier, crossover to 3 1/2" PH-6 work string. TIH, Currently 30 stands in hole. 05/29/14 - Thursday Continue TIH with 8 1/2" OD flat bottom shoe assembly to 45 stands in. Brakes would not hold. Shut well in to repair brakes. Reinstalled brake pads. Continue to TIH to 11,687'. Lay out 2 singles. PU RU power swivel. Begin washing milling @ 3 bpm 547 psi, 4-5K torque 2-3K weight on shoe. Wash ream mill to 11,708', lost returns. Stripper rubber began leaking. Soft closed annular. Total fluid lost 350 bbls. RD power swivel and stripper head. Fill hole with 40 bbls FIW. POOH with milling assembly and work string from 11,708'. Stop 1/2 hour and repair 3 1/2" YT elevators, bolts broke on slip retainer plate. Currently POOH. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 05/30/14 - Friday Finish POOH with 8 1/2" shoe assembly. No recovery of debris. Break out assembly and laydown. PU MU 8 1/8" overshot with wavy bottom guide with 4 1/2" dress off pads dressed with 4 1/2" grapple, extension, 6 1/4" drilling jars, (10) 4 3/4" drill collars, 6 1/2" intensifier crossover to 3 1/2" PH-6 work string. TIH. Found leak in seals on right angle drive. Ordered new seals. Replaced seals. No leaks. Performed rig maintenance while waiting on seals. Continue TIH. Currently 20 stands off bottom. 05/31/14-Saturday Finish TIH with 8 1/8" overshot, w/ wavy bottom guide, 4 1/2" dress off pads, 6 1/4" drilling jars, (10) 4 3/4" drill collars, 6 1/4" intensifier, crossover to 3 1/2" PH-6 work string to 11,698'. Tagged obstruction 10' high. Attempt to mill through obstruction. Pumping 3 bpm, torque 7K plus, varied weights and rpm's. No luck. Pump well bore lubricator chemical to improve hole lubricity. Rig right angle drive gear teeth broke. Shut in well. Ordered out Eline and downhole camera. Ordered new right angle drive. RAD gear box arrived 20:30 on platform. Remove and install drive shaft hub on gearbox, install gear box, align shafts, install guards and chains. Test right angle gear box. Currently rigging down power swivel. Total down time 11.5 hours. Total fluids loss to well 143 bbls. 06/01/14 - Sunday RU Eline with downhole camera. Test packoff, leaking. POOH with camera. Get another packoff pump. Pump 200 bbls. to Trading Bay. TIH with camera. Test camera every approximate 2000'. TIH to 11,657'. Camera quit working. Checked camera. Reheaded Eline twice. Checked Eline unit. Would not work. Get another Eline unit. RU new Eline unit. TIH to 11,696' DPM. 11,657' WLM. Circulate at 1 1/2 bpm. Had visibility then lost it. Could not clear up camera lens. POOH with Eline. Clear camera lens. Lower workstring 8'. TIH to 11,668'. On depth at 11,668'. Currently pumping to Trading Bay to clear fluid. 06/02/14 - Monday TIH with Eline/downhole camera to 11,701' WLM. Circulate from Waterflood to Trading Bay to clear wellbore fluids. Unable to see. Pumped 280 bbls. Moved up hole 221' to clear fluid. Went back down to 11,681' WLM. Circulate at 3 bpm, still no visibility. Hydrocarbons coming in to fast to clear up. POOH with Eline. POOH with overshot assembly, jars, drill collars and 3 1/2" PH-6 workstring. Pulling slow. Shaft on Right Angle Drive loose. Pull slow to minimize damage. Service draw works and motor. POOH. Break out overshot and lay down. Viewed rolled in overshot guide to 7" OD. Casing collapsed. 06/03/14-Tuesday TIH with 9 5/8" casing scraper, (10) drill collars to 11,698'. Circulate well clean. Pumped at 3 1/2 bpm total of 1610 bbls. Fluid loss of 152 bbls. POOH with scraper assembly. Lay out 10 drill collars in singles. Prepare to test BOPE with Bob Nobles AOGCC Witness. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 06/04/14 - Wednesday Finish laying down (10) 4 3/4 drill collars in singles. PU test plug and 3 1/2 test joint. Install test plug. Test BOPE 250 low/ 3000 high, Annular 250 low / 2500 high, test gas alarms, test Pit gain/loss alarm. All test good. Witnessed by Bob Nobles, AOGCC. PU MU 9 5/8 casing test packer. TIH to 1750 set packer and test to 500 psi for 15 minutes. Continue TIH to 10,750' set packer. Attempt to pressure up, having problems with rig pump. Hooking up to waterflood. Pressured up to 1500 psi. Not holding pressure. Currently pulling up hole 1000'. Will retest. 06/05/14 - Thursday POOH FROM 10,759' TO 9,766'. SET 9-5/8" PACKER & ATTEMPT TO TEST CASING @ 9,766' WITH NO SUCCESS. POOH F/9,766' TO 8,824'. ATTEMPT TO TEST WITH NO SUCCESS @ 8,824'. BEGIN TO POOH F/8,824'. FOSTER TONGS NOT BREAKING PIPE. R/D FOSTER TONGS & R/U MCCOY TONGS. POOH TO 6,968'. TEST CASING TO 1500 PSI. (HELD SAME) TIH TESTING CASING TO LOCATE LEAK. CASING LEAK BETWEEN 7,816' TO 7,826', TEST 9-5/8" CASING AT 7,816' TO 1500 PSI ON CHART FOR 30 MINUTES. POOH F/7,816' TO SURFACE WITH 3.5" PH -6 WORKSTRING. L/D 9-5/8" TEST PACKER. R/U E -LINE WITH LUBRICATOR. P/U 40 ARM SONDEX 2.75" O.D. CALIPER TOOL WITH GAMMA RAY & RIH SAME. CURRENTLY PERFORMING CASING CALIPER LOG FROM 10,700' UP TO 7500'. 06/06/14 - Friday FINISH RUNNING CASING CALIPER LOG F/10,698' UP TO 7,494'. POOH WITH E -LINE. WHILE ATTEMPTING TO BRING WIRELINE TOOLS TO SURFACE, E -LINE JAMMED TOOLS INTO LUBRICATOR PULLING OUT OF ROPE SOCKET & DROPPING LOGGING TOOLS IN HOLE. ORDER OUT BRADED LINE UNIT & FISHING TOOLS TO RETRIEVE LOST CALIPER TOOLS. SPOT & R/U BRAIDED LINE UNIT, R/U LUBRICATOR & RIH WITH 5.5" LIB, 10" BOW SPRING CENTRALIZER ASSEMBLY. TAG @ 11,543' WLM. POOH & HAD CENTER IMPRESION OF E -LINE FISH TOP. P/U 1-3/8" JDC TO LATCH ROPE SOCKET, 10" BOW SPRING CENTRALIZER, OIL JARS, & SPANG JARS. RIH, ENGAGE FISH @ 11,543' WLM JAR FREE & POOH. L/D CASING CALIPER LOGGING TOOLS (ALL INTACT). R/D WIRELINE. M/U HALLIBURTON HX -4, 9-5/8" RETRIEVABLE BRIDGE PLUG ON 3.5" WORKSTRING. TIH & SET BRIDGE PLUG @ 8,765' RKB WITH 20K DOWN & 10K OVER PULL. RELEASE FROM PLUG & POOH TO 8,735'. BEGIN DUMPING SAND TO CREATE 20' VOID ON TOP OF BRIDGE PLUG FOR SQUEEZING OPERATIONS. 06/07/14 - Saturday FINISH DUMPING SAND, ESTABLISH INJECTION RATES OF 1 BPM @ 225 PSI, 2 BPM @ 500 PSI, 3 BPM @ 850 PSI. POOH WITH 3.5" TUBING FROM 8,735' TO SURFACE. L/D RETRIEVABLE BRIDGE PLUG RUNNING TOOL & P/U 9-5/8" SQUEEZE PACKER. TIH WITH SQUEEZE PACKER ON 3.5" TUBING TO 7,695'. SET PACKER & TEST ANNULUS TO 1000 PSI. ESTABLISH INJECTION RATES, MIX 10 BBL POLY PLUG RECIPE, PUMP 10 BBLS POLY PLUG DISPLACE WITH 60 BBLS FIW. FINAL SQUEEZE PRESSURE 1.5 BPM @ 785 PSI. SHUT DOWN PUMP & LOCK IN 500 PSI ON TUBING. WAITING ON POLY PLUG SQUEEZE TO SET. RECOMMENDED 8 TO 10 HRS WAITING TIME. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 173-001 1 5/4/14 6/30/14 Daily Operations: 06/08/14 - Sunday WAITING ON POLY PLUG SQUEEZE TO SET. ATTEMPT TO TEST POLY PLUG SQUEEZE, INJECTING AT 2 BPM & 820 PSI. MIX, PUMP, & SQUEEZE SECOND 10 BBL POLY PLUG RECIPE. FINAL SQUEEZE PRESSURE OF 1 BPM @ 730 PSI. SHUT DOWN PUMP & PRESSURE DROPPED TO 500 PSI AFTER 3 MINUTES. LOCK IN PRESSURE ON TUBING SAME. WAIT ON POLY PLUG TO SET. ATTEMPT TO TEST SQUEEZE WITH NO SUCCESS. PUMPING IN AT 2.4 BPM @ 930 PSI. MIX & PUMP 10 BBLS OF POLY PLUG SQUEEZE, DISPLACE WITH 56 BBLS OF FIW. FINAL SQUEEZE PRESSURE 1 BPM @ 750 PSI. AFTER 10 MINUTES PRESSURE DROPPED TO 500 PSI. SHUT IN WELL & WAIT ON POLY PLUG TO SET. 06/09/14 - Monday WAITING ON POLY PLUG SQUEEZE TO SET. ATTEMPT TO TEST POLY PLUG SQUEEZE PUMPING 1 BPM. SQUEEZE BROKE DOWN AT 825 PSI. PUMPING IN AT 1 BPM & 780 PSI. DISCUSS OPTIONS WITH HILCORP ENGINEER. UNSET HALLIBURTON RTTS & PREPARE TO POOH. POOH WITH 3.5" TUBING FROM 7,695' TO SURFACE. L/D RTTS & CLEAN RIG FLOOR. MEASURE & CALIPER 9-5/8" CLEANOUT ASSEMBLY. M/U 8-1/2" BEAR CLAW BIT WITH 9-5/8" CASING SCRAPER. TIH WITH 9-5/8" CLEANOUT ASSEMBLY ON 3.5" 12.95# PH-6 TUBING TO 8,373'. REVERSE CIRCULATE 112 BBLS, (2) TUBING VOLUMES AT 2 BPM & 550 PSI. MAKE WIPER TRIP FROM 8,373' TO 7,700'. TIH TO 8,373', REVERSE CIRCULATE 112 BBLS OF FIW, (2) TUBING VOLUMES AT 2 BPM & 550 PSI. POOH WITH 3.5" TUBING. L/D CLEANOUT ASSEMBLY. P/U HALLIBURTON 9-5/8" EZDRILL EZSVB & TIH ON 3.5" 12.95" TUBING AT 2 MINUTES PER STAND. DEPTH @ 0600 HRS = 3100' 06/10/14-Tuesday TIH WITH HALLIBURTON EZ-DRIL EZSVB ON 3.5" 12.95# TUBING F/3,100' TO 7,992'. SET EZSVB WITH 15K DOWN & SHEAR UPPER SLIPS WITH 42K OVER PULL SETTING EZSV AT 7,992'. ESTABLISH INJECTION RATES OF 1 BPM @ 1025 PSI, 2 BPM @ 1400 PSI. UNSTING FROM EZSV & PREPARE TO POOH. POOH FROM 7,992 TO SURFACE. L/D HALLIBURTON EZSV SERVICE TOOL. PUMP 80 BBLS OF NON-PRODUCED FLUID FROM RIG PITS TO TRADING BAY. CLEAN 200 BBL RIG TANK & FILL WITH DRILL WATER FOR CEMENT SQUEEZE OPERATIONS. TEST BOPE PER AOGCC REGULATIONS, TEST ALL BOPE TO 250 PSI LOW & 2500 PSI HIGH. TEST VBR WITH 3.5" TUBING & 4.5" TUBING. ALL TEST WERE GOOD. AOGCC WITNESS WAS WAIVED BY JIM REGG ON 6/10/14 @ 11:11 HRS AND PERMISSION WAS GRANTED TO TEST EARLY. L/D TEST ASSEMBLY & PREPARE TO TIH WITH EZSV SERVICE TOOL FOR CEMENTING. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 06/11/14 - Wednesday FINISHED TESTING BOP'S. P/U HALLIBURTON EZSV SERVICE TOOL & TIH WITH 3.5" 12.95# TUBING TO 7,992'. STING INTO EZSV SETTING 15K DOWN. ESTABLISH INJECTION RATES OF 1 BPM @ 800 PSI, 2 BPM @ 1200 PSI. SPOT & R/U CEMENT BATCH MIXER & PUMP LINES. MIX & PUMP 20 BBLS OF 15.8# CLASS G CEMENT. PUMP 10 BBLS DRILL WATER SPACER AHEAD, 20 BBLS CEMENT, 10 BBLS DRILL WATER SPACER BEHIND & DISPLACE WITH 18 BBLS OF FIW SPOTTING CEMENT IN TUBING. STING INTO EZSV & SQUEEZE 19 BBLS OF CEMENT BELOW RETAINER. FINAL SQUEEZE PRESSURE 3/4 BPM @ 1300 PSI. UNSTING FROM RETAINER & DUMP 1 BBL OF CEMENT ON TOP OF RETAINER. POOH W/ 2 STANDS TO 7,868', REVERSE CIRCULATE 1.5 TUBING VOLUMES, PUMP 30 BBLS CEMENT BALANCED PLUG @ 7,868'. POOH WITH 10 STANDS TO 7,238'. REVERSE CIRCULATE 1.5 TUBING VOLUMES. SECURE WELL & PERFORM HESITATION SQUEEZE. PUMP 2 BBLS PRESSURE INCREASED TO 250 PSI. WAIT 5 MINUTES, PUMP 2 BBLS PRESSURE INCREASED TO 500 PSI, WAIT 5 MIN. PUMP 2 BBLS PRESSURE INCREASED TO 575 PSI. SECURE WELL, LOCKING IN 575 PSI AGAINST SQUEEZE. CLEAN OUT PUMP & CEMENT EQUIPMENT WHILE WAITING ON CEMENT. 06/12/14 - Thursday WAIT ON CEMENT. TEST CEMENT SQUEEZE TO 1500 PSI. HELD SAME. TIH & TAG CEMENT TOP @ 7,571'. POOH WITH 24 STANDS OF 3.5" 12.95# TUBING FROM 7,571' TO 6,070'. RIGHT ANGLE DRIVE ON RIG FAILED, RIG DOWNTIME: CHANGING OUT RIGHT ANGLE DRIVE. NEW RIGHT ANGLE DRIVE ARRIVED ON RIG @ 2300 HRS. CONTINUING TO INSTALL RIGHT ANGLE DRIVE @ 0600 HRS. 06/13/14 - Friday RIG DOWNTIME: INSTALL RIGHT ANGLE DRIVE & CHAIN GUARDS. POOH FROM 6,070' TO SURFACE WITH 3.5'12.95# TUBING. L/D EZSV SERVICE TOOL & PREPARE TO P/U DRILL OUT ASSEMBLY. P/U 8.5" BEAR CLAW BIT, (4) 4-3/4" DRILL COLLARS, 4-3/4" DRILLING JARS, & X-0. TIH WITH 3.5" 12.95# TUBING & TAG CEMENT TOP @ 7,569' DPM. POOH & L/D 35 JOINTS OF 3.5" TUBING ON CATWALK. TIH WITH 3.5" TUBING OUT OF DERRICK TO 7,542'. R/D FOSTER TONGS, INSTALL HALLS HEAD ADAPTOR WITH STRIPPER RUBBER. P/U POWER SWIVEL & PREPARE TO DRILL OUT CEMENT. DRILL CEMENT FROM 7,569' TO 7,658', REVERSE CIRCULATING 3 BPM @ 200 PSI, 89 RPM WITH 4500 - 5300 FT/LBS TORQUE, 5 - 7K WOB. AVERAGE ROP = 12.7 FT/HR. 06/14/14 - Saturday DRILLING CEMENT FROM 7,658' TO 7,900', REVERSE CIRCULATING 3 BPM @ 190 PSI, 87 RPM WITH 4500 - 5500 TORQUE, 9K WOB. AVERAGE ROP LAST 24 HRS = 10 FPH, SERVICE RIG & EQUIP. 06/15/14 - Sunday DRILLING CEMENT FROM 7,900' TO 7,917', REVERSE CIRCULATING 3 BPM @ 190 PSI, 87 RPM WITH 4500 - 5500 FT/LBS TORQUE, 9K WOB. REVERSE CIRCULATE 56 BBLS (1 TUBING VOLUME), TEST 9-5/8" CASING TO 1500 PSI. DRILLING CEMENT FROM 7,917' TO 7,991', DRILL OUT EZSV FROM 7,991' TO 7,993'. GETTING BACK BRASS CUTTINGS & RUBBER OVER SHAKERS. EZSV BROKE FREE AT 7,993' SURFACE LINES BECAME PACKED OFF WITH DEBRIS. CLEAN OUT SURFACE LINES, FOUND LARGE METAL CUTTINGS WITH CEMENT. CHASE REMAINDER OF EZSV DOWN HOLE FROM 7,992' TO 8,129'. TAG SAME, DRILLING ON REMAINDER OF EZSV FROM 8,129' TO 8,132'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 06/16/14 - Monday DRILL OUT CEMENT & EZSV DEBRIS FROM 8,132' TO 8,150' REVERSE CIRCULATING 3 BPM @ 320 PSI, 85 - 100 RPM WITH 2- 5K FT/LBS TORQUE. 7-12K WOB. UNABLE TO ESTABLISH PENETRATION, BIT SEEM TO BE WORN. L/D POWER SWIVEL & PREPARE TO POOH. POOH FROM 8,134' TO SURFACE WITH 3.5" TUBING. L/D JARS, RACK BACK 4-3/4" DRILL COLLARS. CHOMP BIT HAD (2) CIRCULATING PORTS PACKED OFF WITH METAL & CEMENT. HAD GROOVES CUT INTO THE LOWER OUTSIDE DIAMETER OF THE BIT INDICATING POSSIBLE TIGHT CASING. SEND 8.5" BEAR CLAW BIT TO KNIGHT OIL TOOLS TO BE CUT DOWN 1/8", ORDERED OUT 8.5" STRING MILL. SHIP 160 BBLS OF NON PRODUCED FLUID TO TRADING BAY. CLEAN CEMENT OUT OF RIG TANKS. FILL WITH CLEAN FIW. PERFORM HOUSEKEEPING WHILE WAITING ON WINDS TO DIE DOWN. 06/17/14 -Tuesday WAIT ON WINDS TO DIE DOWN FOR HELICOPTER SLING LOAD OF 8.5" STRING MILL. CALIPER & MEASURE 8.5" STRING MILL ASSEMBLY. P/U & TIH WITH 8-3/8" BEAR CLAW BIT, 8.5" STRING MILL, (4) 4-3/4" DRILL COLLARS, & 4-3/4" DRILLING JARS. TIH WITH 3.5" 12.95# TUBING TO 8,100'. INSTALL HALLS HEAD ADAPTOR WITH STRIPPER RUBBER. P/U POWER SWIVEL & PREPARE TO DRILL OUT CEMENT. DRILL CEMENT FROM 8,150' TO 8,195', REVERSE CIRCULATING 3 BPM AT 350 PSI, 87 RPM WITH 5500 - 6200 FT/LBS TORQUE, 2-4K WOB. SURFACE LINES PLUGGED WITH METAL & BRASS, CLEAR LINES & ATTEMPT TO REVERSE CIRCULATE & DRILL. PRESSURE CLIMBING TOO HIGH, POSSIBLY DUE TO RESTRICTION FROM 8.5" STRING MILL. DRILL CEMENT FROM 8,195' TO 8,208'. CIRCULATING DOWN TUBING AT 4 BPM & 375 PSI, ROTATING 87 RPM WITH 5500 - 6200 FT/LBS TORQUE, 2-4K WOB. CIRCULATE AT 4 BPM & 375 PSI, 1/2 ANNULAR VOLUME. TEST LOWER SQUEEZE TO 1500 PSI, HAD 100 PSI LEAK OFF IN 1.5 MINUTE. DRILL CEMENT FROM 8,208' TO 8,239', REVERSE CIRCULATING AT 3 BPM & 375 PSI, HAVING TO SWAP & PUMP DOWN TUBING DUE TO INCREASED PUMP PRESSURE. CLOSE HYDRIL & REVERSE CIRCULATE 3 TUBING VOLUMES PUMPING 3 BPM AT 450 PSI. ATTEMPT TO TEST 9-5/8" LOWER SQUEEZE TO 1500 PSI, HAD 500 PSI LEAK OFF IN 13 MINUTES. 06/18/14 - Wednesday DRILLING, REAMING, & WASHING FROM 8,239' TO 8,540' PUMPING DOWN TUBING TO REAM DOWN & REVERSING OUT WITH HYDRIL CLOSED DUE TO HIGH PUMP PRESSURE. DRILLING CEMENT, SAND & POLY PLUG FROM 8,540' TO 8,574, PUMPING DOWN TUBING AT 3 BPM & 550 PSI, 5500 - 6200 FT/LBS TORQUE, 4-6K WOB, REVERSE CIRCULATE WITH HYDRIL CLOSED 4 BPM @ 550 PSI. TOTAL OF 376 BBLS UNTIL HOLE CLEANED. L/D POWER SWIVEL & REMOVE HALLS HEAD ADAPTOR FLANGE. POOH FROM 8,574' TO 7,502'. P/U 9-5/8" RTTS WITH STORM CHOKE, TIH & SET RTTS 64' BELOW CASING HEAD HANGING OFF 3-1/2" TUBING TO TEST BOPE. P/U TEST JOINTS & PREPARE TO TEST BOPE PER AOGCC REGULATIONS. TEST WITNESS WAIVED BY JIM REGG ON 6/18/14 @ 09:39 HRS. TEST ALL BOPE TO 250 PSI LOW & 2500 PSI HIGH. HOLD ALL TEST ON CHART FOR 5 MINUTES. PERFORM KOOMEY DRAW DOWN TEST. PULL TEST PLUG & L/D TEST ASSEMBLY. INSTALL WEAR BUSHING & PREPARE TO RETRIEVE RTTS. or Hilcorp Alaska LLC � Well Operations Summar t� p Y Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 173-001 1 5/4/14 6/30/14 Daily Operations: 06/19/14 - Thursday STING INTO RTTS, UNSET &PULL TO RIG FLOOR. L/D RTTS & PREPARE TO POOH. POOH FROM 7,502' TO SURFACE WITH 3.5" 12.95# TUBING. L/D 8.5" MILL ASSEMBLY & 8-3/8" BEAR CLAW BIT. HAD GROOVES CUT INTO BIT & STRING MILL. BIT HAD OUTSIDE CUTTERS MISSING. P/U 8.5" MILL TOOTH BIT, (4) 4-3/4" DRILL COLLARS, & 4-3/4" DRILLING JARS. TIH WITH 3.5" TUBING TO 8,554'. TAG SAME. P/U POWER SWIVEL & INSTALL HALLS HEAD ADAPTOR FLANGE WITH STRIPPER RUBBER. BREAK CIRCULATION IN REVERSE WITH 3 BPM & 180 PSI. DRILL, REAM, & WASH CEMENT/SAND FROM 8,554' TO 8,734', REVERSE CIRCULATING 3 BPM @ 180 PSI, 90 RPM WITH 4500-5500 FT/LBS TORQUE, 2-3K WOB. WASH SAND DUMPED ON RBP FROM 8,734' TO 8,754', REVERSE CIRCULATING 3 BPM @ 250 PSI. REVERSE CIRCULATE HIGH VISCOCITY SWEEP TO CLEAN HOLE FOR RBP RETRIEVAL. L/D POWER SWIVEL & REMOVE HALLS HEAD ADAPTOR FLANGE. POOH FROM 8,754' TO 2,895'. 06/20/14 - Friday POOH WITH 3.5" TUBING. L/D 8-1/2" MILL TOOTH BIT & P/U RBP RUNNING TOOL. TIH WITH RBP RUNNING TOOL ON 3.5" TUBING TO 8,754'. WASH SAND FROM 8,754' TO 8,765', "J" LATCH ONTO RBP & PULL FREE. REVERSE CIRCULATE (2) TUBING VOLUMES. TIH WITH RBP FROM 8,765' TO 9,350'. ATTEMPT TO SET RBP REPEATEDLY PUTING 1-3/4 TURN TO LEFT & WORKING PIPE TO GET TORQUE DOWN HOLE WITH NO SUCCESS. PIPE REACHING MAX TORQUE LIMIT ON TOOL JOINTS. POOH WITH 3-1/2" TUBING SLOWLY INSPECTING TOOL JOINTS. FOUND 15 CONNECTIONS THAT WERE LOOSE. TIGHTEN SAME. L/D RBP & RUNNING TOOL. MAKE UP 9-5/8" DRILLABLE BRIDGE PLUG, TIH SLOWLY, RE-TORQUING CONNECTIONS TO 8200 FT/LBS DOWN TO 9,350'. SET DRILLABLE BRIDGE PLUG @ 9,350', PULL 42K OVER STRING WT. & SHEAR OFF PLUG. SLACK OFF & TAG PLUG TOP SAME. POOH WITH 3.5" 12.95# TUBING FROM 9,350' TO SURFACE. 06/21/14 - Saturday P/U 9-5/8" RTTS & TIH TO 9,036'. SET RTTS & ESTABLISH INJECTION RATES OF 1 BPM @ 433 PSI & 2 BPM @ 1150 PSI. POOH WITH RTTS TESTING CASING TO LOCATE UPPER LEAK. TEST CASING AT 8,036' HAD 150 PSI BLEED OFF IN 5 MINUTES. TEST CASING @ 7,910' TO 1500 PSI & RECORD ON CHART FOR 30 MINUTES. HELD SAME. POOH FROM 7,910' TO SURFACE WITH 3.5" TUBING. L/D RTTS, CLEAN SAND FROM 30 BBL MIXING TANK & FILL WITH 30 BBLS OF DRILL WATER FOR CEMENT JOB. P/U 3.5" MULE SHOE & TIH WITH 3.5" TUBING FROM DERRICK TO 9,133'. R/U CEMENTERS. HOLD PJSM. TEST LINES TO 250 LOW & 3500 HIGH. PUMP 10 BELS OF DRILL WATER SPACER AHEAD. MIX & PUMP 33 BBLS OF 15.8 PPG CLASS "G" CEMENT, 2 BBLS OF DRILL WATER SPACER BEHIND, DISPLACE WITH 61 BBLS OF FILTERED INLET WATER. POOH WITH 10 STANDS OF 3.5" TUBING FROM 9,133' TO 8,502', REVERSE CIRCULATE 1.5 TUBING VOLUMES. BEGIN HESITATION SQUEEZE ON CASING HOLE @ 9,098'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 06/22/14 - Sunday PERFORM HESITATION SQUEEZE ON LOWER CASING LEAK @ 9,098'. SQUEEZE TOTAL OF 16 BBLS, FINAL SQUEEZE PRESSURE OF 850 PSI. CLOSE IN WELL & WAIT ON CEMENT. REMOVE SHAKER PACKAGE & CLEAN SHAKER TANK, SLIP & CUT 120' OF DRILL LINE. PERFORM HOUSE KEEPING WHILE WAITING ON CEMENT. OPEN WELL, TIH FROM 8,502' TO 8,815', TAG CEMENT WITH 5K DOWN. POOH TO 8,048'. R/U CEMENTERS. HOLD PJSM. TEST LINES TO 250 LOW & 3500 HIGH. PUMP 10 BBLS OF DRILL WATER SPACER. MIX & PUMP 30 BBLS OF 15.8 PPG CLASS "G" CEMENT, 2 BBLS OF DRILL WATER SPACER BEHIND, DISPLACE WITH 53 BBLS OF FIW. POOH WITH 3.5" TUBING FROM 8,048' TO 7,415', PERFORM HESITATION SQUEEZE ON UPPER CASING LEAK. SQUEEZE TOTAL OF 15 BBLS, FINAL SQUEEZE PRESSURE OF 1400 PSI. CLOSE IN WELL & WAIT ON CEMENT. WAIT ON CEMENT. SEND 160 BBLS OF NON PRODUCED FLUID TO TRADING BAY. CLEAN 200 BBL ACTIVE RIG TANK. GO THRU RIG PUMP CHECKING VALVES, SEATS, LINERS, & SWABS. 06/23/14 - Monday WAIT ON CEMENT. OPEN WELL, TIH FROM 7,502' TO 7,939'. TAG CEMENT WITH 5K DOWN. POOH TO 7,935'. TEST 9-5/8" CASING TO 1500 PSI ON CHART FOR 30 MINUTES. (HELD SAME), POOH WITH 3.5" TUBING LAYING DOWN 48 JOINTS ON CAT WALK TO DRILL OUT CEMENT. POOH WITH 3.5" TUBING FROM 6,444' TO SURFACE. L/D MULE SHOE & CLEAN RIG FLOOR. P/U 8.5" MILL TOOTH BIT, (4) 4-3/4" DRILL COLLARS & 4-3/4" DRILLING JARS. TOTAL BHA LENGH = 142.61'. TIH WITH 3.5" TUBING TO 7,917'. P/U POWER SWIVEL & INSTALL HALLS HEAD ADAPTOR FLANGE WITH STRIPPER RUBBER. DRILL CEMENT FROM 7,939' TO 8,196', REVERSE CIRCULATING 3.5 BPM @ 430 PSI, 2-4K WOB, 90 RPM WITH 5000-5500 FT/LBS TORQUE. CIRCULATE BOTTOMS UP & TEST 9-5/8" CASING TO 1600 PSI ON CHART FOR 30 MINUTES. HAD 60 PSI DROP OFF IN 30 MINUTES. (TEST GOOD). DRILL, WASH, & REAM CEMENT FROM 8,196' TO 8,630', REVERSE CIRCULATING 3.5 BPM & 450 PSI. 06/24/14 -Tuesday DRILL, REAM & WASH CEMENT FROM 8,630' TO 9,251', REVERSE CIRCULATING 3 BPM & 480 PSI. 90 RPM WITH 5000 - 5500 FT/LBS OF TORQUE, 4-5K WOB. REVERSE CIRCULATE 1.5 TUBING VOLUMES & TEST 9-5/8" CASING AT 9,251' TO 1500 PSI ON CHART FOR 30 MINUTES. HAD 20 PSI BLEED OFF. (TEST GOOD). WASH FROM 9,251' TO 9,350'. DRILL OUT EZSV FROM 9,350' TO 9,353' REVERSE CIRCULATING AT 3 BPM & 440 PSI. CHASE REMAINDER OF BRIDGE PLUG DOWN HOLE FROM 9,353' TO 11,676'. SET DOWN 10K. POOH TO 11,646', REVERSE CIRCULATE (2) TUBING VOLUMES AT 3 BPM & 440 PSI. SEND NON PRODUCED TRANSFER FORM TO TRADING BAY TO CIRCULATE HOLE CLEAN FOR PERFORATING. PUMP 130 BBLS OF NON PRODUCED FLUID FROM RIG TANK TO TRADING BAY. CLEAN RIG TANK WHILE DISPLACING K-17 WITH CLEAN FIW SENDING RETURNS TO TRADING BAY. 06/25/14 - Wednesday DISPLACE K-17 WELL WITH CLEAN FIW FLUID. TOTAL 1200 BBLS NON PRODUCED FLUID PUMPED FROM WELL AND MUD TANKS TO TRADING BAY. POOH WITH 3.5 PH6 WORKSTRING. L/D (6) 4 3/4'' DRILL COLLARS, BIT. R/U AND TEST BOP'S ON 3 1/2'' AND 4 1/2'' TBG TO 250 PSI LOW/2500 PSI HIGH ON RAMS, ANNULAR 250 PSI LOW/2500 PSI HIGH (ALL TESTS GOOD). WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. FINISH CLEANING CEMENT OUT SLUGGING PIT. M Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-17 50-733-20248-00 1 173-001 1 5/4/14 6/30/14 Daily Operations: 06/26/14 - Thursday PICKING UP TCP ASSEMBLY. TOTAL LENGTH 946.59'. TRIP IN HOLE WITH TCP ASSEMBLY ON 3 1/2" WORK STRING, TAGGED 43' IN ON STAND #173 = 11,674' (PM). SPACED OUT AND INSTALLED SAFETY VALVE WITH TCP ASSEMBLY SETTING ON BTM. R/U ELINE W/ (2) 111/16" WT. BARS + GR/CCL. TESTED LUBRICATOR TO 2000 PSI (TEST GOOD.) RIH W/ GR/CCL AND PULLED CORRELATION STRIP- DETERMINED THAT BOTTOM SHOT WAS AT 11,656' (ELM) USING DIGITAL PERF CORR LOG TO TIE IN WITH. DECISION WAS MADE TO POOH AND DROP ONE GUN. POOH W/ ELINE AND RIGGED DOWN. POOH WITH TCP ASSEMBLY @ 6:00 DEPTH 4,000'. 06/27/14 - Friday FINISH POOH WITH 3 1/2" WORK STRING. POOH WITH TCP GUNS. L/D BOTTOM GUN - TOTAL LENGTH 21.00'. PICK UP GUNS, TRIP IN HOLE WITH 4 1/2" GUNS ON 3 1/2" WORKSTRING, TAGGED UP @ 11,674' (PM). HELD PJSM. R/U ELINE W/ (2) 1 11/16" WT BARS + GR/CCL. TESTED LUB TO 2000 PSI (TEST GOOD). RIH WITH GR/CCL TO 10,750' AND PULLED CORRELATION STRIP USING DIGITAL PERF CORR LOG. DETERMINED THAT PIPE WOULD HAVE TO BE PULLED 9' TO PUT TCP GUNS ON DEPTH. POOH AND R/D EL. M/U HANDLING SUB WITH PUMP -IN AND SAFETY VALVE. PULLED UPHOLE 9' PLACING TCP GUNS ON DEPTH. CLOSED PIPE RAMS. R/U TO REV WITH CHOKE ACCESS AND DROPPED BAR (7 MINS TO REACH BTM FIRING GUNS). ZERO PRESSURE INCREASE. OPENED NEEDLE VALVE TO FIND SLIGHT SUCTION. PERF WELL FROM 11,646' TO 10,828', 4 1/2" GUNS @5 SPF DIFFERENT INTERVALS. REVERSED CIRC 2 TB VOLUMES AT 2 1/4 BPM 150#s. TRACE OF OIL AND GAS AT BTMS UP. MINIMUAL FLUID LOSS. R/D HANDLING SUB, PUMP -IN AND FOSV. PULLED 17 STANDS SLOWLY PLACING GUNS ABOVE PERF INTERVAL. CHECKING FILLUPS. REMOVED SLIPS AND WIPER RUBBER TO WATCH FLUID LEVEL IN STACK. HOLE TAKING 1 BBL PER/HR. R/U, POOH LAYING DOWN WORKSTRING WHILE KEEPING HOLE FULL. 06/28/14 -Saturday POOH LAYING DOWN 3.5" PH6 WORKSTRING,TOTAL 314 JTS. LAY DOWN 4 1/2" PERF GUNS. ALL GUNS FIRED. RIH WITH 3 1/2" PH -6 OUT OF DRK. POOH LAYING DOWN SAME, TOTAL 58 JTS. OFF-LOADED ESP EQUIPMENT AND 4 1/2" PRODUCTION STRING. RIGGED UP ALL EQUIPMENT TO RUN DOWNHOLE PUMP. BEGAN M/U PUMP ASSEMBLY. P/U 4 1/2" 12.6# L-80 IBTC PRODUCTION TBG. 06/29/14 -Sunday FINISH P/U ESP ASSY. INSTALL POWER CABLE. BEGAN RUNNING IN HOLE WITH ESP ASSEMBLY PICKING UP NEW 4 1/2" 12.6# IMP BTC MOD TUBING OFF DECK. DRIFT SAME WITH FULL SIZE DRIFT. PLACING CABLE CLAMP ON EVERY OTHER JOINT. WITH 5,010' OF ASSEMBLY AND TBG IN HOLE, SPLICE WAS MADE IN ESP CABLE. CONTINUED RUNNING ASSEMBLY IN HOLE DEPTH @0:600 HRS 7,331'. 06/30/14 - Monday CONTINUED IN HOLE WITH 345 JTS 4 1/2" 12.64 IMP BTC MOD TUBING WITH ESP ASSEMBLY. M/U FMC HANGER AND TERMINATED ALL ESP CABLES AND CHEMICAL LINES. LANDED HANGER WITH BTM OF ESP @ 10,010' (SLACKOFF WT 82K, PICKUP WT 143K). L/D LANDING JTS. PJSM. BEGAN CLEARING RIG FLOOR TO R/D SAME. SCOPED DERRICK DOWN AND LEANED OVER TO MAKE ROOM TO REMOVE BOP'S. N/D BOPs AND RISER. P/U TREE AND N/U TO WELLHEAD. TESTING VOID TO 250#s LOW/ 5000#s HIGH. INSTALLING FLOWLINE. FINAL REPORT FOR K-17. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ��(Il� DATE: July 11, 2014 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Verification Petroleum Inspector TBU K-17 PTD 1730010 Hilcorp Inc. Thursday, July 10, 2014: 1 witnessed the No Flow verification of well K-17 aboard the King Salmon platform in the Trading Bay Unit/McArthur River Field. I met Dave Meyers (lead op.) on location this morning and we went over the status of the well. The well had been shut-in for 24 hours waiting on a No -Flow test. There was 0.3 psi read on the tree cap using a 30 psi test gage with recent calibration sticker affixed. I verified proper alignment of all valves and that the IA was in communication with the tubing. I observed the well in this state for 3 hours with no change in shut-in pressure. The tubing/annulus was bled to atmosphere at an initial rate of 750 scf measured on an Erdco "Armor -Flo" meter (SN 031189) recently calibrated and capable of measuring 180-1800 scf. This flow fell off quickly (<3 minutes) to zero flow. The tubing was routed through a one inch hose to a bucket of water and at one inch depth of water no bubbling was observed. This well meets the criteria for no -flow status. -' Attachments: Equipment Calibration Certificate Non -Confidential SCANNED NOV 20 2014 2014-0710 No-Flow_TBU_K-17_lg.docx 1of1 7�,a�14 (P-Tli"3 i73Wtc1 This is to certify that this instrument has been calibrated for the fluid conditions specified on the purchase order and embossed on the nameplate. Measuring devices that are traceable to the United States National institute for Standards and Technology (NIST - formerly National Bureau of Standards) were used for this calibration. T ` chniclan Date t Instrument Serial Number EROCO Engineering Corporation 721 Custer Av ♦ Post Office Box 6318 Evanston, IL 60204-6318 USA p-rn-43 -001 Ferguson, Victoria L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, June 25, 2014 8:29 AM To: Ferguson, Victoria L (DOA); Schwartz, Guy L (DOA) Cc: Juanita Lovett Subject: K-17 Well With Moncla 404 Rig - Sundry# 314-179 PTD -173-001 - Program Change Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please be advised that since we were successful in getting a pressure test on the 9-5/8" casing, we will not be running a scab liner in this well. We will be proceeding with step # 9 of the approved Sundry 314-179 after we test bop's later today. Not running the Scab liner will allow us to fish the dropped ESP out of this well when we have a larger rig on the next pull. Removing this dropped ESP is important to Hilcorp because its removal will give us access to the Hemlock Bench 4 for re -perforating. Thanks for your help on this. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 1 r Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, June 25, 2014 8:29 AM To: Ferguson, Victoria L (DOA); Schwartz, Guy L (DOA) Cc: Juanita Lovett Subject: K-17 Well With Moncla 404 Rig - Sundry# 314-179 PTD -173-001 - Program Change Victoria, Please be advised that since we were successful in getting a pressure test on the 9-5/8" casing, we will not be running a scab liner in this well. We will be proceeding with step # 9 of the approved Sundry 314-179 after we test bop's later today. Not running the Scab liner will allow us to fish the dropped ESP out of this well when we have a larger rig on the next pull. Removing this dropped ESP is important to Hilcorp because its removal will give us access to the Hemlock Bench 4 for re -perforating. Thanks for your help on this. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1 i -61 t.. V--(7 PM h-30010 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, May 23, 2014 2:06 PM S L3, IA To: 'Bob Finch - (C)' V Cc: 'Ted Kramer' Subject: RE: Moncla Rig 404 BOPE Test Report 5-14-2014 Don't need to count time you are testing CMV offline; we have allowed that before with a couple caveats: 1) Full BOPE test must be performed when AOGCC witnessing 2) Include statement in Remarks that you have done this; as was reported the test time looks inordinate and raises a red flag (remarks will save you and me time) Seems like we have been seeing a lot of leaks attributed to the test manifold; needs to be addressed Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Bob Finch - (C) [mailto:bfinch@hilcorp.com] Sent: Friday, May 23, 2014 12:50 PM To: Regg, James B (DOA) Cc: Ted Kramer Subject: RE: Moncla Rig 404 BOPE Testort 5-14-2014 I failed to send the chart with Bob Finch WSM King Sal Office 90 6-6699 Cell S -n-578-2246 lind ram test charted. See attached. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, May 23, 2014 12:13 PM To: Bob Finch - (C) Subject: RE: Moncla Rig 404 BOPE Test Report 5-14-2014 Vit, u� Describe the time scale for the chart ^^s cL6,w BOPE Test report says test took 3 hours to complete; that is half the time of typical BOPE test for M404; are you documenting the test differently than previous? -� While tripping out of the hole we closed the HCR and tested the choke manifold independently. Test valves 1,2 and 3. Then we test 9,4 and 5. Then test 6 and 7. Then test valve 8 alone. This saved time of testing while performing other task. This was 1 % hours. Going forward we can count this time as part of the test time. When we were out of the hole we tested the Annular alone then valves 10 and coflex are tested with IBOP. IBOP, K3, valve 10 with coflex and pipe rams, then K2, HCR, TIW valve, then K1 and C1. Then do accumulator draw down and build up, pull test joint and test blinds alone from choke manifold back through coflex with K1 closed. Report indicates no failures; please explain the following: Test 1— HP test appears to be FP since it was re -pressured Test 1 was a leak on the test manifold. Not valves. Test 2 — Same -� The same test manifold leak as above. Test ? (labeled v-3, 6,9) — appears to FP low test (This should be 4,5,9 as written on chart) After the test it was noticed that there was not 250 psi pumped and noted on the chart. Se we pumped up to 250 psi and re -charted. Human error. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or lim.regg@alaska.gov. From: Bob Finch - (C) Finailto:bfinch(&hilcorp.com] Sent: Thursday, May 15, 2014 11:23 AM To: Regg, James B (DOA) Subject: RE: Moncla Rig 404 BOPE Test Report 5-14-2014 Mr. Regg, Please see attached BOPE test charts. Bob Finch WSM King Salmon Office 907-776-6699 Cell 832-578-2246 From: Regg, James B (DOA) ailtoJim.regg@alaska.gov] Sent: Wednesday, May 1 014 12:39 PM To: Bob Finch - (C) Subject: RE: Mon Rig 404 BOPE Test Report 5-14-2014 Please send-Eopv of test chart Jim Regg 2 Regg, James B (DOA) From: Bob Finch - (C) [bfinch@hilcorp.com] Sent: Thursday, May 15, 2014 11:23 AM To: Regg, James B (DOA) Subject: RE: Moncla Rig 404 BOPE Test Report 5-14-2014 Attachments: Moncla Rig 404 BOPE Test charts 5-14-2014.pdf Mr. Regg, Please see attached BOPE test charts. WSM King Salmon Office 907-776-6699 Cell 832-578-2246 From: Regg, James B (DOA) [mailtoJim.regg@alaska.gov] Sent: Wednesday, May 14, 2014 12:39 PM To: Bob Finch - (C) Subject: RE: Moncla Rig 404 BOPE Test Report 5-14-2014 Please send copy of test chart Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Bob Finch - (C) [mailto:bfinchCabhilcorp.com] Sent: Wednesday, May 14, 2014 9:07 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Juanita Lovett Subject: Moncla Rig 404 BOPE Test Report 5-14-2014 Bob Finch WSM King Salmon Office 907-776-6699 Cell 832-578-2246 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION�g��2�1 BOPE Test Report Submit to: lim.regq(d)_alaska.gov AOGCC. I nspectors(a_)alaska. gov Phoebe. brooks(o)alaska.gov Contractor: Moncla Rig No.: 404 DATE: 5/14/14 Rig Rep.: Steve Solis Rig Phone: 907-776-6699 Rig Fax: Operator: Hilcorp Alaska LLC Op. Phone: 907-776-6690 Op. Fax: Rep.: Bob Finch E -Mail bfinch@hilcorp.com Well Name: TBU K-17 PTD # 1730010 Operation: Drlg: Test: Initial: Test Pressure: Rams: 250/3000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P Misc BOP STACK: Stripper Annular Preventer #1 Rams #2 Rams #3 Rams #4 Rams #5 Rams #6 Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve BOP Misc Workover: X Weekly: X Annular: 250/1500 Explor.: Bi -Weekly Valves: 250/3000 MUD SYSTEM: TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelly 0 NA NA Lower Kelly 0 NA NA Ball Type 1 P NA Inside BOP 1 P 1 Blinds FSV Misc 0 NA Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm 0 NA Trip Tank NA NA 1 13 5/8"M P Pit Level Indicators P NA 1 2 7/8 x 5 FP Flow Indicator NA NA 1 Blinds P Meth Gas Detector P P 0 NA H2S Gas Detector P P 0 NA MS Misc 0 NA 0 NA 0 NA 1 2 1/16 P 1 2 1/16 P 3 2 1/16 P 0 NA 0 NA CHOKE MANIFOLD: Quantity Test Result No. Valves 10 P Manual Chokes 1 P Hydraulic Chokes 1 P CH Misc 0 NA Test Results Quantity Test Result) Inside Reel valves 0 NA ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3200 P Pressure After Closure 1500 P 200 psi Attained 39 P Full Pressure Attained 181 P Blind Switch Covers: All stations Yes Nitgn. Bottles (avg): 2550 ACC Misc 0 NA Number of Failures: 1 Test Time: 3.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Hydraulic hose quick connect on pipe rams leaked. Replaced quick connect retested good. While tripping out of the hole we closed the HCR and tested the choke manifold independently. This saved 1.5 hrs test time. 24 HOUR NOTICE GIVEN YES X NO Waived By Jim Re Date 5/11/14 Time 17:03 ky'kTA M Test start 0:00 Finish 3:00 Form 10-424 (Revised 03/2013) 2014-0514_BOP_Moncla404_TBU_K-17.xlsx 170, © ~� a°off iso0 '� A 100 -100 r f ,(nap'. CHART \ RONN0. MC MPo METErQ -S00p of1 S Yoi. c - - k CA j(i_' . _ r 00 CHART PST\0.o� . btE j {y 11 yy t j 1 4 L 0 M rAKEN OFF OA TION 17 --�- �- REMARKS &jp�l �I la/,, d ✓ / . f `"; ° os 000/ --A 00 • � �; \ \`. , \ `\ �,� _, lir ., � _ �/ i J � Q \ `� r�0 O O OA ye \� t y Nd 9 S •� �-_ �,� 'meq 7� �` f / p / �. jam' -i• p��.\� fj X00 • /�_ _ _ -1000- O J 1 •� j fill +1-- --t i 5Qp-� \ 4 '� �,r l Ij`� •J/CHART N0. MC MP -5000 '\ .o 0 0 0 o METER - �, TAKEN OFF , CHART PUT ON - M _ -"- u�CD LOCATION 6 REMARKS00 1 o ; 'Q i' p01, oi �'£)p f \ - _ - Y \� pp O� 00 r� J .. p q ;r 4 �r�.... Wd 9 �. Soo l O / CHART ` . MG � mp-5U0 1 0. LO f 0C 4 Of F \114 -411k y 00 G-. 00, 1 \ O OS GO lb 49 r , _ 1 Nd 9 1750010 Regg, James B (DOA) From: Bob Finch - (C) [bfinch@hilcorp.com] --� Sent: Friday, May 23, 2014 12:50 PM ��'�� S z�l 14 - To: Regg, James B (DOA) Cc: Ted Kramer Subject: RE: Moncla Rig 404 BOPE Test Report 5-14-2014 Attachments: BOPE Test Chart Blind Rams 5-20-2014.pdf I failed to send the chart with the blind ram test charted. See attached. Bob Finch WSM King Salmon Office 907-776-6699 own Cell 832-578-2246 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, May 23, 2014 12:13 PM To: Bob Finch - (C) Subject: RE: Moncla Rig 404 BOPE Test Report 5-14-2014 Describe the time scale for the chart BOPE Test report says test took 3 hours to complete; that is half the time of typical B7 fest for M404; are you documenting the test differently than previous? While tripping out of the hole we closed the HCR and tested the choke manifol independently. Test valves 1,2 and 3. Then we test 9,4 and 5. Then test 6 and 7. Then test valve 8 alone. This save time of testing while performing other task. This was 1 % hours. Going forward we can count this time as part of4he test time. When we were out of the hole we tested the Annular alone then v es 10 and coflex are tested with IBOP. IBOP, K3, valve 10 with coflex and pipe rams, then K2, HCR, TIW valve, th K1 and Cl. Then do accumulator draw down and build up, pull test joint and test blinds alone from choke manifold ck through coflex with K1 closed. Report indicates no failures; please explain the followi Test 1— HP test appears to be FP since it was re- ressu Test 1 was a leak on the test manifold. Not val S. Test 2 — Same The same test manifol/error. Test ? (labeled v-3, 6,ow test (This should be 4,5,9 as written on chart) After the test it was ns not 250 psi pumped and noted on the chart. Se we pumped up to 250 psi and re -charted. Huma Jim Regg Supervisor, tions AOGCC 333 ve, Suite 100 Anchorage, AK 99501 907-793-1236 1 _ 0 -1800 0 iCHART N0. MC MP -5000 p 00 v 'METER. !�� r �r' t•, j TA;tN OFF - 'CHAR T PUT ON - - - M +_ p Q LOCATION N A REMARKS �C /A�904/; l�¢.► Y�1rVpS,j ^ j 00 IZ \. c� ,dt I Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, May 23, 2014 11:31 AM To: 'Bob Finch - (C)' Cc: Juanita Lovett; Brooks, Phoebe L (DOA) Subject: RE: BOPE Test Report Moncla Rig 404 King Salmon Platform - Well TBU K-17 5/20/2014 Which test was blind rams? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or Iim.regg@alaska.gov. From: Bob Finch - (C) [mailto:bfinch(�0hilcorp.com] Sent: Wednesday, May 21, 2014 11:10 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Juanita Lovett Subject: BOPE Test Report Moncla Rig 404 King Salmon Platform - Well TBU K-17 5/20/2014 Bob Finch WSM King Salmon Office 907-776-6699 Cell 832-578-2246 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: lim.regg(a)alaska.gov AOGCC.Inspectors(a.alaska.gov phoebe.brooks @alaska.gov Contractor: Moncla Rig No.: 404 DATE: 5/20/14 Rig Rep.: Steve Solis Rig Phone: 907-776-6699 Rig Fax: Operator. Hilcorp Alaska LLC Op. Phone: 907-776-6690 Op. Fax: Rep.: Bob Finch E -Mail bfinch@hilcorp.com Well Name: TBU K-17 PTD # 1730010 Operation: Drlg: #1 Rams Workover: Test: Initial: #3 Rams Weekly: Test Pressure: Rams: 250/3000 Annular: MISC. INSPECTIONS: TEST DATA Choke Ln. Valves Test Result HCR Valves Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig NA PTD On Location P Hazard Sec. NA Standing Order Posted I' Misc NA BOP STACK: Quantity Stripper 0 Annular Preventer 1 #1 Rams i #2 Rams 1 #3 Rams 0 #4 Rams 0 #5 Rams 0 #6 Rams 0 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves 3 Check Valve 0 BOP Misc 1 Size/Type Test Result NA 13 5/8"M P 27/8x5 P Blinds 1' NA NA NA NA 2 1/16 P 2 1/16 P 2 1/16 hub clam CHOKE MANIFOLD: Quantity Test Result No. Valves 10 P Manual Chokes I P Hydraulic Chokes l P CH Misc 0 NA X Explor.: X Bi -Weekly 250/1500 Valves: 250/3000 Visual FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly o NA Lower Kelly 0 NA Ball Type 1 P Inside BOP I P FSV Misc 0 NA MUD SYSTEM: Visual Alarm Trip Tank NA NA Pit Level Indicators P NA Flow Indicator NA NA Meth Gas Detector P P H2S Gas Detector P P MS Misc 0 NA Quantity Test Result Inside Reel valves 0 NA P NA ACCUMULATOR SYSTEM: FP Time/Pressure Test Result System Pressure 3200 P Pressure After Closure 1500 P 200 psi Attained 39 P Full Pressure Attained 181 I' Blind Switch Covers: All stations Yes Nitgn. Bottles (avg): 2550 ACC Misc 0 NA Test Results Number of Failures: 1 Test Time: 5.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Well head Hub Clamp leaking. Tighten and retested good. 24 HOUR NOTICE GIVEN YES X NO Waived By Jim Regg Date 5/18/14 Time 07:27 Witness Test start 20:00 Finish 01:00 Form 10-424 (Revised 03/2013) 2014-0520_BOP_Moncla404_TBU_K-17.xlsx 400 r --Cop0 7-2 °5t' i,. j-/ -' 500 `V IN \ (jri}.hk-l.utti�tMti�� RT N0. MC MP -5000 r CNA N: �• HART Pl , 7N 00 LOCATION t(1 O O O t O t7 5t O 1 ARKS X�OOOt- oog S �....��. Wd g 3500 -� _ 3000- -2500 --1500 00 \ 6,X O 0 �\ . MF t t NPR i - a 17 CV J �006 V/1 r J \ \ z i Q o -- 5 y _ 1 \. - d 9 v 1;- THE STATE A„'aLkaC . of A /,, (7 Tr fV` r _ 42: 1sC r) \ �, � 2 _� 333 West Seventh Avenue , GOVERNOR SEAN PA I Anchorage, Alaska 99501 3572 Main: 907 279 1433 ALA61° nox. 907.276.7542 Ted Kramer SCANNED AUG 8 2 Q J _ Sr. Operations Engineer /3 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-17 Sundry Number: 314-179 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 7 Foerster Chair h44- DATED this 2 day of April, 2014. Encl. V STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION OTS t J 2114. APPLICATION FOR SUNDRY APPROVALS A 0(A7( C 2QAAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate New Pool 0' Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations❑ Perforate I]• Pull Tubing 0 Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well 0- Stimulate 0 Alter Casing 0 Other. install ESP 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development 0• 173-001 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic 0 Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20248-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A • Will planned perforations require a spacing exception? Yes 0 No 0 4 Trading Bay Unit!K-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 - McArthur River Field/Hemlock Oil Pool r /cidk_ 6- Q;I 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): 12,120 9,787 12,025 9,713 2,501',6,980'&7,018' 2,501'(fish) . Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13-3/8" 2,183' 2,037' 3,090 psi 1,540 psi Intermediate Production 12,096' 9-5/8" 12,096' 9,768' 6,820 psi 4,230 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 'Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic% See Schematic 4-1/2" 12.6#/L-80 ±30' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A/N/A N/A/N/A 12.Attachments: Description Summary of Proposal 0• 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 • Exploratory 0 Stratigraphic❑ Development 0 Service 0 14.Estimated Date for 15.Well Status after proposed work: \ Commencing Operations: 4/15/2014 Oil t1/71-4.'.I. Sas 0 WDSPL ❑ Suspended t 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer(cr�.hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature .</✓ ®4 Phone (907)777-8420 Date 3/18/2014 /� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\i-(- \-"1 `t Plug Integrity ❑ BOP Test V/ Mechanical Integrity Test ❑ Location Clearance 0 Other: X-- 2 S ce) PS L .6O f 7-i.:5 t- ,X- NNa - F-/o,., " -i., S-f- rc2cayv RBDMS MAY 1 0 2014 Spacing Exception Required? Yes 0 No 11 Subsequent Form Required: /Q— 110L( APPROVED BY - Approved by: egi p COMMISSIONER THE COMMISSIONg � Date: ¢. -2 U 3 ..Z 8•N A ' PI qx 1 G,ik \'AlgOrytWoctiproval. Submin Form ane Form 10-403(Revised 10/2012) Approved l i n i ff�� Attachments in Duplicate . Well Work Prognosis IIWell: K-17 Hilcorp Alaska,LLC Date: 03/14/14 Well Name: King Salmon K-17 API Number: 50-733-20248-00 Current Status: Suspended Leg: Leg#1 NE Corner Estimated Start Date: April 15, 2014 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 173-001 First Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) Second Call Engineer: Dan Marlowe (907)283-1329 (0) (907) 398-9904 Current Bottom Hole Pressure: 3,653 psi @ 9,247' TVD/ 11,437 MD Calc from offset Phoenix Gauge reading (K-30 11/26/2012 to 12/02/2012 7 day buildup) Maximum Expected BHP: 3,653 psi @ 9,247'TVD/ 11,437 MD From Phoenix Gauge Max.Anticipated Surface Pressure: 0 psi (Based on 0.439 psi/ft gradient from offset producer(K-30). Brief Well Summary The K-17 well was suspended in May of 2002 following a fire that destroyed the King Salmon Platform Rig. During this fire,the ESP that was hanging in the slips was dropped into the well along with the Electrical cable attached to the tubing. Well was secured and two easy drill squeeze packers (EZSV)were set at 7,018' and 6,980' respectively. A retrievable bridge plug(WRP)was then set at 2,501'. One joint of 4-1/2"tubing was hung off of the tubing hanger and the well head installed. The workover plan for this well is clean all packers/plugs and junk down to 11,800', re-perforate as per the Final Approved Perforation Form, run an ESP and place the well on production. J Ceini►,'yk/ P. t'ct,01r 0 dr6v,'Ze.of i al TO(/ ,ljGv Zia. y ,•051C-- 04 1. MIRU Moncla rig 404. 2. Bleed down any pressure, 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 test). 3. PU 8-1/8"overshot on 3-1/2"WS. RIH to TOF @ 2,501'+/-. Engage fish,and work/jar/pull fish free. POOH W/fish. I 4. PU 8-1/2" mill on 3-1/2"WS. RIH to top of EZSV at 6,980'and mill up EZSV#1 and#2 at 7,018'. S .,k.(( S'r"'a• Continue in hole to tag TOF at 8,013'. Circ bottoms up and POOH w/mill. lit. 5. PU RIH with overshot and grapple on 3-1/2"WS. RIH to TOF at 8,013'. Engage fish and POOH (1, > laying down 4-1/2"tubing,Electrical cable and Centrilift ESP. 4-;s& ESP b. 6. PU RIH with bladed mill on 3-1/2"WS to CIBP @ 11,800'. Circ hole clean, POOH with Mill. 7. PU RTTS packer. RIH to 10,800'. Srt packer and pressure test casing to 1 500 2sii-.Chart same for 30 minutes. 8. Unset and POOH with RTTS Packer. 9. PU RIH W/TCP guns. RU E-line. Log Guns on depth and fire. 10. Circulate any perf gas out of well. Pick up guns above top Perf,shut down. 11. Monitor well for one hour,shoot fluid levels as needed to determine fluid loss and insure the well is static. 12. POOH laying down Perforating guns. 13. PU and RIH with new ESP assembly. Well Work Prognosis We11: K-17 Hilcorp Alaska,LLC Date: 03/14/14 14. Set bottom of ESP at 10,778'+/-. Hang off well. 15. ND BOP, NU wellhead and test. 16. Turn well over to production. Attachments: 1. Current Well Schematic 2. Current Wellhead Diagram 3. Proposed Well Schematic 4. Proposed Wellhead Diagram 5. BOP Drawing ,--wiettiiimitm King Salmon Platform Well#K-17 UNOCAL() Completion AO 5/1/02 KB=101PAN& CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. ►., IIIS =. 7111GIItitger 13 61 K-55 BTC 12.415 Surf 2183' ' IV OW 9-5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 9-5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' Tubing: ►:, /4-1/2" 12.6# L-80 7 IBTC 3.958 Surf 10,654' 4_3-1/2" 9.2 L-80 8rd EUE 2.992 11887' 11909' JEWELRY DETAIL Top Btm ID Item 33.7 3.958 UH-TC-1AEN 12"x 4-1/2"FMC IBTC top/bot Tbg 1338"@2183' Hngr w/control line ports plugged&4'/z" IBTC pin x ❑ pin nipple w/3"type'H'BPV installed Z. 1 jt.of 4'/2"tbg hanging below hanger for weight Lwow =41.1 V1R1'(a25:11 (Nike:portion 11,882 5.0" Otis`WD'Perm Isolation packer ofsettigtodmtopofplug) 11,897 2.750" Camco`D'Nipple 9Sppg( 11,909 2.992" Otis 3%2"WLEG(E.O.T.) \ E v@9;�' trine , • EbV@A18' 11,852 N/A Otis'WD'ph,20.6'SB ext.,Camco 4'/2"DB-6 f nipple,4'/2"WLEG,milled loose&pushed to bottom a Top of fish 8,013'1'D ill Llpg CaQB --0' ICM011I i = 1-13-1,2,3,44 FISH#1: Otis'WD'pkr,20.6'SB ext.,Cameo 4'/z"DB-6 nipple,4'/z"WLEG,milled loose& pushed to bottom(above isolation packer)(3/31/2002)Top of fish tagged @ 11,852'MD c Qw@11s'In FISH#2: 600 HP 725 Series HC12000 ESP Assembly,4'/2"L-80 AB Mod IBTC tbg,3 SFO-2 SPMs&+/-3700'ESP cable on top of CIBP @ 11,800'(4/20/02)Top of fish @+/-8013'MD 12 i° HB5-9 D 21 ? PERFORATION DATA Zone Top Btm Amt Comment F116HB-1 11,420' 11,460' 40' HB-2 11,482' 11,540' 58' HB-2 11,552' 11,592' 40' HB-3 11,592' 11,655' 63' HB-4 11,655' 11,774' 119' 95/8 � HB-5 11,856' 11,876' 20' SQZD MilLHB-6 11920 11975 55' PB1D=12,Q2S ID=12120 Nit ECI.EPNZL E-44°@380B Updated by:JLL 02/24/14 King Salmon Platform HPROPOSED Well # K-17 Hi4rorp Alaska,LLC Completion: Future KB=100'AMA, CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61 K-55 BTC 12.415 Surf 2183' 9-5/8 40.0 RS-95 BTC 8.835 Surf 7,031' 9-5/8 43.5 RS-95 BTC 8.755 7,031' 12,096' Tubing: 4-1/2" 12,6# L-80 3.958 Surf ±10,628' JEWELRY DETAIL i II No. Depth Item 1 33.7' Hanger ' 133/8"@2183' 2 ±10,778 Bottom of ESP 3 11,800' CIBP 2 in PERFORATION DATA Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt Comment G-1 ±10,828' ±10,846' ±8,793' ±8,806' 13 Future G1-6 G-2 ±10,878' ±10,907' ±8,830' ±8,852' 22 Future G-2 ±10,922' ±10,946' ±8,863' -±8,881' 18 Future G-3 ±10,990' ±11,007' ±8,913' ±8,926' 13 Future 1.$1,2,3,4 G-4 ±11,040' ±11,086' ±8,950' ±8,984' 34 Future G-4 ±11,127' ±11,139' ±9,015' ±9,024' 9 Future G-5 ±11,183' ±11,249' ±9,057' ±9,107' 50 Future G-6 ±11,318' ±11,350' ±9,160' ±9,185' 25 Future 3 CIBP@11,800'ND Future HK-1 ±11,419' ±11,457' ±9,238' ±9,268' 30 lg . ...?lig3 I-IBS-8IM HK-1 11,420' 11,460' 9,239' 9,270' 40' HK-2 ±11,482' ±11,539' ±9,288' ±9,332' 57 Future HK-2 11,482' 11,540' 9,288' 9,333' 58' 21). ? HK-2 ±11,551' ±11,584' ±9,342' ±9,374' 33 Future HK-2 11,552' 11,592' 9,342' 9,374' 40' S}g( HK-3 11,592' 11,655' 9,374' 9,423' 63' HK-3 ±11,595' ±11,721' ±9,376' ±9,475' 126 Future HK-4 11,655' 11,774' 9,423' 9,517' 119' HK-4 ±11,722' ±11,773' ±9,476' ±9,516' 51 Future MIL 958"csg HK-5 11,856' 11,876' 9,581' 9,597' 20' SQZD HK-6 11920 11,975' 9,631' 9,674' 55' PBTD=12,025 TD=12,12j M3oc HaEAWE-44°@3811 Updated by:JLL 03/18/14 11 King Salmon Platform K-17 Current Hi�r,p Ala.kr.ILL 03/18/2014 King Salmon Tubing hanger,FMC-UH- K-17 TC-1A-EN,13 5/8 5M X 4%3 24 X 13 3/8 X 9 5/8 IBT lift and susp,w/4"type IS BPV—Has special 3" Type H BPV pup installed underneath hanger BPV installed in hanger ._I �1,, 1 'U ,,, 1\11_4 Valve,Swab,WKM-M, 4 1/16 5M FE,HWO,EE ar � . , Valve,Wing,WKM-M, trim ~> 4 1/16 5M FE,HWO,EE trim r: 0 or / N� 41 Valve,Master,WKM-M, �p0 co) 4 1/16 5M FE,HWO,EE I%-( o O' trim O U Adapter,FMC-ASP,13 5/8 5M API clamp X 4 1/16 5M,w/7" co D A� \l extended neck pocket I i•i' i' �� Unihead,OCT type 3,13 5/8 5M API I' 1-1 ') p 'pow \c ! �, hub top X 13 3/8 BTC casing bottom, I_ �F..1- �} 1 `-- w/1 2 1/16 5M SSO on lower '' 41/0 section,1-2 1/16 5M SSO on middleF. section,3-2 1/16 5M SSO on upper section,IP internal lockpin assy I • I- .I ., +,{ All annular valves are I• 2 1/16 5M FMC 120 lir Starting head,FMC, i 211A 2M X 24"SOW, 1 1 �• �� VV/1-3 1/8 2M EFO �� I) 1�� ` 'i' „t .L:f I i 24', 13 3/8” - 9 5/8" King Salmon Platform K-17 Proposed Mewls:►larks,L«: 03/18/2014 King Salmon Tbg hanger,OCT-UH-TC-1A- K-17 ESP,13 X 4'2 IBT lift and 24 X133/8X95/8X4'/: susp,w/4"Type H BPV profile,3/8 cont control line port BHTA,Bowen,4 1/16 5M FE x 7"-5 Stub acme Bowen top ° 1 4 _ _ _44 Valve,Swab,WKM-M,4 1/16 5M FE,HWO,EE trim Valve,Wing,SSV,WKM-M,3 1/8 5M FE,Iw/OMNICI oper,EE trim i nal awe MI ,il zjj Valve,Wing,WKM-M,2 1/16 5M ;_: FE,HWO,DD trim �, a �h` . E i IS_ Valve,Master,WKM-M,41/16 5Mat R �� FE,HWO,EE trim /11 �! (moi 1. wi 511Z-;:6 t9 .aEc Valve,Wing,WKM-M,3 1/8 5M FE, ai * HWO,EE trim *'`\ - UI_I .j°` - Adapter,OCT-AS-ESP,13 5/8 5M API hub X 41/16 5M stdd top,w/2-''/%control I ® II line exits,prepped w/OCT 400-4 pocket I 11 > 1 iOlt. V �r` All unihead annular valves,2 Unihead,OCT type 3,13 5/8 5M API '''"` ' 1/16 5M FE OCT-20,HWO hub top X 13 3/8 BTC casing bottom, E. �� 8� i4..: w/1-2 1/16 5M SSO on lower section,1-2 1/16 5M SSO on middle _ - section,3-2 1/16 5M S5O on upper 2 section,IP internal lockpin assy ' _ ' , �.I 11 - Valve,OCT-20,3 1/8 2M FE, Starting head,OCT,211/4 2M FE X '• i ' I'° F.1 : ? HWO • 24"SOW,w/1-3 1/8 2M EFO,full M - 1 ' -111 set of lockpins I _ 24 " 13 3/8" 9 5/8" 49:'( 8: /„ 4 King Salmon Platform 2013 BOP Stack(Moneta) 09/19/2013 Itlilrorp A1;4%101,11,4.: • 11111Av III III III III III III IiI' II 11 I. AEI 3.74' .,, Iii lit III AI iii All If! III lf! I1! Ilfl F Cl ` w-U leS�re Variable 27/8-5 4.67' eee� ,r= 1 ® 111"11' =.11111111111 I1 13 5/8-5000 II sa =Blind Rams iii Iii Iii iii iii _ Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses irCy --4 ---"--- •:: 1ll 111111 lil Ill ' 't../1141 -- 2 OCI!.:. r. i_ In Iii w III ill - Iil Ili IlI III Itl Riser,13 5/8 5M FE X 13 5/8 SM API#13 hub 13.70' Moncla Rig 404 BOP Test Procedure Hileorp Alaska,LLCAttachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, King Salmon WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing(test)joint to lift-threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test,open same. Moncla Rig 404 BOP Test Procedure Hikorp Alaska,LLC Attachment#1 ii) Valves, 3,4,9. After test,open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test,open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test,open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in)side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW(or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. II Moncla Rig 404 BOP Test Procedure Hiloorp Alaska,TLC Attachment#1 Diagram A-1: King Salmon BOP stack and Riser Arrangement—Typical for Single Completion • • Iil tit iii lit iii iii iii lit 3.74' 111 lit ill lii Iil liaa 1 11111 Iv III III -® - _ II Variable 2 7/8-5 4.6T i' ® - - =ewer _ .,ii 13 5/8-5000 1 —c Blind Bans Iil III Ill III Iil __ Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses Ill I!1'11 II' 11 1.1.1" 0!- :''. ' 2.00 8� -` A '. p, .i, •. lit Ill ill iii iii `SI gig III III iii III I11 Riser,13 5/8 5M FE 013 5/8 5M API#13 hub 13.70' Moncla Rig 404 BOP Test Procedure HiIco�t�Alaska,(.I.f Attachment#1 Diagram B: King Salmon Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves i pIit Mid�l .11- - RI _ w "` `I' Chokes are 90 degrees off in drawing in order to show detail : . IE. _,, a , _.it: AMID Swaco MEW ii, - Slit11111400164 III I! : _., . _ iris ,« „ „sem;,,, alk*" t Illik ,, , lit a III II ;ii N I From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3'/4' Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3 '/4" Ball port, 6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3 '/4" Ball port, 6000psi working pressure #10 National Ball Valve B1560, 1 'A" Ball port, 6000psi working pressure . . . .. Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 5T Eu Ja I ,l` Q.J C ) t r—l. ` r_ Illinil O d 0 • CD I- CO a 1111 E o Z0 d CQ vyF I[I � M e� W 1.-11 �. o 0 Lir �rQz W 0 o I= z � ddcr» C 5 W U � p V z o `-' z o Q c J=.J 1 JOZL1J ma J D 0 Ct Z-_-) Moncla Rig 404 II BOP Test Procedure Hileorp Alaska,LLC Attachment#1 12 ii 11 g V z meq.. a J _ E a M J,, g Y tV= O G U e u W QC..) (`= D;. ma- E,-. 0 z 0 G7 r E.D Z I z H UJ 0 cpQza Do o � p � � �..._._ o as Cz �CtW Sd — Z Om _J J c u Q1--- W _vw Z (1 L G a J(..1 J _Li__1 Z' Q^ V Z 1 Q J D N0 LL_ U • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/08/10 Inspector: Chuck Scheve Operator: UNOCAL Well Name: TBU K -17 Oper. Rep: Chris Johnson PTD No.: 1730010 Oper. Phone: Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Offshore Suspension Date: 04/30/02 Date AOGCC Notified: Sundry No.: 302 -144 Type of Inspection: Initial Wellbore Diagram Avail.? Well Pressures (psi): Tubing 0 Photos Taken? Yes IA 260 - By Operator - OA 40 Condition of Wellhead: Flow line disconected and blinded. Master valve and Swab valve in place. Condition of Surrounding Surface good Location: Follow Up Actions None Needed: Attachments: None REVIEWED BY: Insp. Supry J IIf I //t Comm 'two PLB 09/2010 2010- 1008_Suspend_TBU_K- 17_cs.xls SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSSIOAT ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager 3 — 0 0' Union Oil Company of California PO Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Hemlock Oil 8s Middle Kenai G Oil Pool, TBU K -17 Sundry Number: 310 -357 Dear Mr. Brandenburg: StdV#&V NOV I 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. Since ely issioner DATED this d day of November, 2010. Encl. . • • Page 1 of 1 Aubert, Winton G (DOA) From: Kanyer, Christopher V [Chris.Kanyer @chevron.com] Sent: Tuesday, November 16, 2010 8:03 AM To: Aubert, Winton G (DOA) Subject: TBU K -17 (PTD 173 -001) Winton, Per our earlier phone conversation, we request a variance from the suspended well plugging requirements, regulation 20AAC25.112, on our sundry request, for suspended well renewal, for well TBU K -17 (PTD 173 -001). Please let me know if you have any questions regarding this request. Thanks. Chris Kanyer Technical Assistant Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 11/16/2010 • ' �i �L�,!'� • Ck..N stilt- (zow STATE OF ALASKA OCT 2 8 2010 ALASKA OIL AND GAS CONSERVATION COMM ISSI �s , ail& SCONE, APPLICATION FOR SUNDRY APPROV S Anc 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Reauest for Suspended Well Q Renewal 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 ' Exploratory ❑ 173 -001 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20248 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El Trading Bay Unit K -17 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0017594 [King Salmon Platform] McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pool 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): t 12,120 9,787 12,025 9,713 2,501', 6,980', & 7,018' 2,501' (fish) Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,183' 13 -3/8" 2,183' 2,037' 3,090 psi 1,540 psi Intermediate Production 12,096' 9 -5/8" 12,096' 9,768' 6,820 psi 4,230 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4-1/2" 12.6# L -80 +/ -30' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): N/A / N/A N/A / N/A 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Service ❑ 14. Estimated Date for N/A 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: N/A WINJ F] GINJ F] WAG El Abandoned ❑ Commission Representative: GSTOR El SPLUG El 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name 9 Timothy C. Brandenburg Title Drilling Manager Signature f �- Phone 276 -7600 Date 6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31(3 - Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ El Location Clearance , I ' Other: I' l l Y s K A� +o 2.0 X X-t L5 . I ( i. o11 1 A . t [s✓ K'#' { `C. lA'Lct Pr' s( woott f 'I Subsequent Form Required: /jo dt.e APPROVED BY Approved by: Z LER THE COMMISSION Date: Form 10-403 Revised 1/2010 R 1 G I N A L Submit in Duplicate Suspended Well Data Well: K -17 Surface Location: 694' FSL, 83' FEL, Sec 17, T9N, R13W S.M. Permit to Drill: 173 -001 API: 50- 733 - 20248 -00 AOGCC Inspection Date: 9/25/10 AOGCC Inspector: No witness Size Pressure (psi) Tubing 4 -1/2" 0 Casing 9 -5/8" 260 13 -3/8" 36 - 24" 25 *Note: Wellhead pressures to be recorded daily. Other Notes: • There has been no change in Well K -17's mechanical condition, based on monitored pressure trends. The well was suspended in good mechanical condition in April, 2002, with two cement retainers and a wireline retrievable plug isolating the completion interval below them. • Formation pressure from surface to the top of the completion interval is a normal pressure gradient. The G -Zone and Hemlock completion intervals are sub - normally pressured due to offset well production. • The proposed plan for Well K -17 is to maintain its suspended status and continue monitoring the well until the King Salmon Platform production is shut -in and an overall platform abandonment plan begins execution. Attachments: • Current Well Schematic • 3 Year TIO Plot King Salmon Platform ALASKA WRILLING Well # K -17 V N O CAL 9 Completion AO 5/1/02 10 =100 ANEL CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. T1BGfhW 13 -3/8" 61 K -55 BTC 12.415 Surf 2183' 9 -5/8" 40.0 S -95 BTC 8.835 Surf 7,031' W � 9 -5/8" 43.5 S -95 BTC 8.755 7,031' 12,096' Tubing: 4 -1/2" 12.6# L -80 IBTC 3.958 Surf 10,654' ( 1h 3 -1/2" 9.2 L -80 8rd EUE 2.992 11887' 11909' JEWELRY DETAIL Top Btm ID Item 33.7 3.958 UH- TC -IAEN 12" x 4 -1/2" FMC IBTC top/bot Tbg Hngr w/ control line ports plugged & 4 '' /2 ' 113TC pin x in nipple w/ 3" type 'H' BPV installed ❑ I jt. of 4 ' /2 " tbg hanging below hanger for weight VM@2tW (iutm patian 11,882 5.0" Otis 'WD' Perm Isolation packer ofsetto Wont+opofpt 11,897 2.750" Camco 'D' Nipple 9-5 pug 11,909 2.992" Otis 3'/2" WLEG (E.O.T.) brine E&V *m MV a ll$' 11,852 N/A Otis 'WD' pkr, 20.6' SB ext., Camco 4'h" 1313-6 nipple, 4 ' /2" WLEG, milled loose & pushed to bottom Topafm ND G2,44 WPM G� 1 -12WIM I$1,2,3s4 FISH #1: Otis 'WD' pkr, 20.6' SB cxt., Camco 4'/2" DB-6 nipple, 4'/2" WLEG, milled loose & pushed to bottom (above isolation packer) (3/31/2002) Top of fish tagged @ 11,852' MD CW@IU ND FISH #2: 600 HP 725 Series HC12000 ESP Assembly, 4'/2" L-80 AB Mod IBTC tbg, 3 SFO -2 SPMs & +/ -3700' ESP cable on top of CIBP @ 11,800' (4/20/02) Top of fish @ +/ -8013' MD I$5 -8W PERFORATION DATA Zone Top Btm Amt Comment I�6 G -2 10,890' 10,910' 20' G -2 10,928' 10,948' 20' G -3 10,990' 11,010' 20' G -4 11,030' 11,090' 60' HB -1 11,420' 11,460' 40' 9 �,� HB -2 11,482' 11,540' 58' HB -2 11,552' 11,592' 40' PBFD HB -3 11,592' 11,655' 63' MlXH3 EPM.E 4C@3800 HB -4 11,655' 11,774' 119' HB -5 11,856' 11,876' 1 20' SQZD HB -6 11920 11975 55' K -17 Schematic 5- 1- 02.doc Revised By JFB Date: 5/1/02 Pressure N N W W A CT O CT Cl CT O CT O O Cl Cl O Cl Cl O O O 10/17/07 I I 1/17/08 w 1 O � _ w - I 4/17/08 7/17/08 b O 10/17/08 b K fD C K CD 0 1/17/09 Rp fD 4/17/09 y i 7/17/09 r � 10/17/09 ~ J 1/17/10 4/17/10 7/17/10 10/17/10 STATE OF ALASKA ALASAL AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well LJ Plug Perforations LJ Stimulate U Other L�� Suspended Well Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Inspection Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: Permit to Drill Number: Name: Development Exploratory ❑ 173 -001 P Box 1 247 Anchorage, AK 99519 Strati ra hic Service 3. Address: O o 96 g p ❑ ❑ kAPI Number: 50- 733 - 20248 -00 QO 7. Properly Designation (Lease Number): 8. Well Narr and Number: ADL0017594 [King Salmon Platform] Trading Bay Unit K -17 9. Field /Pool(s): \ \ McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pool 10. Present Well Condition Summary: 2,501, 6,980, & Total Depth measured 12,120' feet Plugs (measured) 7,018 feet true vertical 9,787 feet Junk (measured) 2,501' (fish) feet Effective Depth measured 12,025 feet Packer (measured) N/A feet true vertical 9,713 feet (true vertical) N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,183' 13 -3/8" 2,183' 2,037' - 3,090 psi 1,540 psi Intermediate Production 12,096' 9 -5/8" 12,096' 9,768' 6,820 psi 4,230 psi Liner Perforation depth: Measured depth: N/A True Vertical depth: N/A Tubing (size, grade, measured and true vertical depth): 4 -1/2" 12.6# L -80 + / -30'MD + /- 30'TVD Packers and SSSV (type, measured and true vertical depth): N/A N/A N/A N/A { 11. Stimulation or cement squeeze summary: { Intervals treated (measured): ! ' N/A Treatment descriptions including volumes used and final pressure: y N/A Q�i. LII�iet� Ain* iAi 12. Representative Daily Average I or I c Oil -Bbl Gas -Mcf I Water -Bbl r sure Tubing Pressure Prior to well operation: 0 0 10 1260 psi 0 psi Subsequent to operation: 0 0 10 1260 psi 0 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Develo ent❑✓ Service ❑ Daily Report of Well Operations N/A 15. Well Status after work: Oil Gas Lj WDSPL Lj Well Remains in'SUSP' Status = => GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature � Phone 276 -7600 Date 10/11/10 ABDMS OCT Form 10 -404 Revised 7/2009 Submit Original Only Suspended Well Inspection Data Well: K -17 Surface Location: 694' FSL, 83' FEL, Sec 17, T9N, R13W S.M. Permit to Drill: 173 -001 API: 50- 733 - 20248 -00 AOGCC Inspection Date: 9/25/10 AOGCC Inspector: No witness Size Pressur (psi) Tubing 4 -1/2" 0 i Casing 9 -5/8" 26 13 -3/8" 24" 25 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • None. Attachments: • Current Well Schematic • Picture(s) • Plat - 1 /4mile radius of wellbore King Salmon Platform ALASKA RRILLING Well # K -17 U N O CAL 76 Completion AO 5/1/02 I0 =1W ANIS CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTNI. 13 -3/8" 61 K -55 BTC 12.415 Surf 2183' 9 -5/8" 40.0 S -95 BTC 8.835 Surf 7,03 W � 1' 9 -5/8" 43.5 S -95 BTC 8.755 7,031' 12,096' Tubing: 4 -1/2" 12.6# L -80 IBTC 3.958 Surf 10,654' 3 -1/2" 9.2 L -80 8rd EUE 2.992 11887' 11909' JEWELRY DETAIL Tov Btm ID Item 33.7 3.958 UH- TC -IAEN 12" x 4 -1/2" FMC IBTC top/bot Tbg 133'9„(k2W Hngr w/ control line ports plugged & 4'/z" IBTC pin x in nipple w/ 3" type `H' BPV installed ❑ h 6 1 jt. of 4 ' /2" tbg hanging below hanger for weight w;r a*l' (Note P0wM 11,882 5.0" Otis `WD' Perm Isolation packer ofsethtgtoolattopct'ft 11,897 2.750" Camco `D' Nipple 9.5 11,909 2.992" Otis 3 ' /2" WLEG (E.O.T.) tine l *M EZS'V ae, 19 11,852 N/A Otis `WD' pkr, 20.6' SB ext., Camco 4'/z" DB -6 nipple, 4'h" WLEG, milled loose & pushed to bottom Topaffistt 8,Oli' ND G2A4 10mg CK" LCV11A HB-V,2�4 FISH #1: Otis `WD' pkr, 20.6' SB ext., Cameo 4 %:" DB•6 nipple, 4'/2" WLEG, milled loose & pushed to bottom (above isolation packer) (3/31/2002) Top of fish tagged @ 11,852' MD t1EP @11,80 ND FISH #2: 600 HP 725 Series HC12000 ESP Assembly, 4'/2" L-80 AB Mod IBTC tbg, 3 SFO -2 SPMs & +/ -3700' ESP cable on top of CIBP @ 11,800' (4/20/02) Top of fish @ +/ -8013' MD PERFORATION DATA Zone Top Btm Amt Comment 1136 G -2 10,890' 10,910' 20' G -2 10,928' 10,948' 20' G -3 10,990' 11,010' 20' +t G -4 11,030' 11,090' 60' -113 1 -1 11,420' 11,460' 40' HB -2 11,482' 11,540' 58' 9 �„� g XJp HB -2 11,552' 11,592' 40' PBTD =lZ=TD =IZW 1-113-3 11,592' 11,655' 63' MwH0LEMUE - 44' @38001 1 11,655' 11,774' 119' 1-113-5 11,856' 11,876' 20' SQZD HB -6 11920 11975 55' K -17 Schematic 5- 1- 02.doc Revised By JFB Date: 5/1/02 KING SALMON WELLSLOT DIAGRAM 01/01/10 K -6RD K -19 K -12RD2 /i K -23 g S „0 K -24RD2 S/1 6' K -22RD 29 5' 31 7 K -25 , S/1 K — 3R D K -17 s/i s/1 K -20 s' S/1 s/1 K -10RD 27 i S '5 �+ K -18RD L 1 S 26 K -26 s K -21 RD K -1RD2 0 K -30 Leg #4 z Leg #1 NW Corner NE Corner 0 3 0 0 Producer Dual Gas Well Injector Completion S K -2RD E 0 0 K -13RD2 S/} o 30 s 4 K -7RD V) 21 13 jS /I 31 LD NO WELLS o 20 WATER INJECTION K -11 12 s/i K -5 ° EQUIPMENT 32 a a 0 19 11 S/ v 17 K -4RD s/i s� 18 {o K -15RD m U Leg #3 Leg #2 Z SW Corner SE Corner �. _. oil NOW # CFA slow AR as s ' g 4 �k k x 1 =ds, }" E k 2 a � na4 ��N M k ,.�,. �� ,. ill ,� � ,' r9 - „m _. �,.„,„,� .a. � iM,R ��' 6 .�. .,�,;:� .�� ►.. . , _,» . 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'.s �� t $ '`tl ,' I� # „ } } ., yu t. d x VI N MI 4 , ti,,. � 1 I s r~ ; F a low 1,r i r i ,t I < 7 i F ay wKY- OQ 006 ,l1��+ 00 00 00E 09 0-ft oos jr z � d w t , r a q< * s a �k �z s f a Chevron a ft.- A., 0""40,0— March 31, 2009 \ -1 '3 - e, C--., \ Dale Haines Union Oil Company of California Alaska Area Operations P.O. Box 196427 Manager Anchorage, AK 99519-6247 Tel 907 263 7951 Fax 907 263 7607 Email Daleah@chevron.com Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Suspended Wells Dear Commissioner Foerster, 9p is oil SC#X1 OCT 08 2 14 Please find the attached corrections to the suspended and long term shut in well list as provided in your letter dated January 28, 2009. As per our discussion the submitted list needs to be expanded to include additional wells that may not currently be identified on the list provided by the Commission. We also provide the Commission with an annual shut in well report that is sent to Steve McMains. This report was mailed to the Commission on March 30, 2009. At this time I cannot validate that we have provided the Commission with a comprehensive list of all suspended wells so it is our intention to validate the two lists and to review our records to ensure that we have accurately responded to the request. We will therefore endeavor to provide a comprehensive list to the Commission in the next two weeks. Chris Myers will contact Jim Regg to discuss the scheduling inspections of the suspended wells in 2009. If you have any questions about this submittal, please contact myself. Sincerely, r� „I Dale Haines Alaska Area Operations Manager Attachment Cc: Tim Brandenburg Chris Myers Dave Cole Union Oil Company of California / A Chevron Company http://www.chevron.com Corrections for the referenced list of suspended and long-term shut-in wells operated by UNOCAL. Well Name API# PTD Current Listed Status Corrected Status Bruce 18742 #40 50-733-20339-00 181-022 Suspended Shut -In SRU 14-15 50-133-10145-01 100-146 Suspended Shut -In SCU 243B-04 50-133-20489-00 199-055 Suspended Shut -In i,�`• ,'� SARAN PAULA, GOVERNOR ALASKA 01Llt AGAS 33: W 7th AVENUE. SUITE 100 CONSIERlIVA.nON COPDnSSION AW HORAGE.ALASKA 99501.3539 PHONE (907) 279-1.433 January 28, 2009 FA>'. (907) 27E•7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 I)ale Maines UNOCAI. 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of' Revised Suspended Wells Regulations and Rcquest for Verification of Suspended and Shut -In Well Information Dear Mr. I laines: Inclosed are the Alaska Oil and Gas Conservation Commission's revised re<�ulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. Por each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg(t?alaska.gov. h!uxC •_>>>; questions rn4orA;no )h!S notice, -!ease contact Tn!n M_ilinrj.^r al 0117-791- 1250 or tom.maundcr@alaska.gov. Sincerely, Cathy P. Foerster Commissioner linclosures Opermor Suspended and Sllt,t In Wells UNION OIL CO OF CALIFORNIA /Meld Current U:Ue or Permit A1'I Number Well Mmic ~talus SUMIS Surface Luca ion .................................................... I.rase(s)................................... BIRCH HILL 165-001-0 50-133-10029.00.00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY 8-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13 W SM FEE-CIRI GRANITE PT 11 IV 4- S 196-045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T ION R 12 W SM ADL0018761 196-013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4/22.12006 2427 FNL 1303 FWL Sec 13 T ION R 12 W SM ADL0018761 197-145-0 50-733-20479-00.00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T ION R 12W SM ADLO374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T ION R 12W SM ADL0018761 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 SUSP 9116/1989 834 FNL 676 FEL Sec 12 T ION R 12 W SM ADL0018742 167.042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL Sec 31 T 11 N R 11 W SM ADL0018742 178-096-0 50.733-20119-00.00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11W SM ADL0018742 179.017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9120/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11N R 11W SM ADL0018742 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T ION R 12 W SM ADL0018742 MCARTHUR RIVER 169.095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8N R 13W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13W SM ADL0017594 SWANSON RIVER 199-055-0 50-133-20489-00.00 SOLDOTNA CK UNIT 24313-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7N R 9W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7N R 9W SM FEDA028997 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 423-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7N R 9W SAA FEDA028996 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWI. Sec 22 T 8 N R 9 W SM FEDA028406 172-007.0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 vWL Sec 4 T 7N R 9W SM FEDA028399 162-030-0 50-133-10143.01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8 N R 9W SM FEDA028406 " • s II'eduesdt{r, Jenown, 114, 2009 ✓ e Z — J �w o �V %Cos TP� Loo �,s c(;W c? n�°t rfai'/ Operator Suspended and Shut In Neils UNION OIL CO OF CALIFORNIA Field Current Date of Permit AM Number Well Name Status Status Surface Location .................................................... Lease(s) ................................... TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY ST A-20RD SUSP 4/23/1990 1604 FSL 559 FEL Sec 4 T ON R 13 W SM ADL0018731 14u JYerinesrlrrt-, Arrmrrig 14, 2009 20 A:%,(: 25.1 0. Susuended wells aIHOWULI under 20 AAC 25.J05. the cominissron will, upo:. .rtion by IC operator under (b) of this section, approve the suspension of a well i; (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to Mdicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (I3) is a candidate for rcdrilling; (C) has potential value as a service well; or (D) is located on a pad or platform with active producing or service wells; and (2) the operator justifies to the commission's satisfaction why the well should not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (H) imprudence of security maintenance of a completed well in a shut-in status; (C) need (br pool delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted 'o and approved by the commission before plugging operations are begun; in a well for which suspension is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) a statement of proposed work, including (A) information on abnormally geo-pressured strata; (B) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans Cor cementing, shooting, testing, and removing casing; (ll) if thu Apphc,ttion for Sundry Approvals is subinittcd alter begir.l:ing work, the manic of the representative of the commission who provided oral approva, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submit:ed to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31.05.035 (c), if the information is described in 20 AAC 25.(51(b) ; or (2) for the time that the infonnation has value as a trade secret, if tac infonnatien is not described in 20 AAC 25.07] r but is determined by the commission: to constitute a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.1 l 2. except that the requirements of 20 AAC 25.112(d) do not apply If (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge; plug capped with 50 feet of cement or a continuous cement plug cx,cnding 200 feet within the interior casing string is placed at or above 300 feet below the surface- the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or piatlonn assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall raaintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170 a (2) or (b) or with 20 AAC 25J 72(c) (2) or (d), as applicable. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 �-l'3_oc,k ' a a a a O SARAH PALIN, GOVERNOR ALASKA OIL AND GAS333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale Haines UNOCAL 3 800 Centerpoint Dr. Ste 100 G E Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Haines: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, 0 1-2 1 14t Cathy P. Foerster Commissioner Enclosures ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 i Anchorage AK 99503 I I A. kNgnature � E) -,Received b (Primed Name) I C. PW.f D. Is delivery address different from item 0 ❑ Y s If YES, enter delivery address below: ❑ No I (S�Ivice Type rtified Mail 11 Express Mail ❑ Registered C:fReturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes I 2. Article Number (Transfer from service label) ?005 1820 0001 2499 6 019 PS Form 3811, February 2004 Domestic Return Receipt 102595•02•M-1540 Postal Ir CERTIFIED MAIL,,, RECEIPT rq r-3 I (Domestic Mail Only; No Insurance Coverage Provided) -D Er 11 qq At GkAi l ` `, ru SP SP pS,T Postage $ $4.59 9 ocertified Fee $2.70 (P C3 O Return Receipt Fee (Endorsement Required) $2,20 —s = p Z 0 rU Cal Restricted Delivery Fee (Endorsement Required) $0. W op A I w AK r� Total Postage 8 $5.49 ec4cG 01/28lc LnDale Haines 13 Sent To C UNOCAL (`-Streef, Apt. N -o- or PO Box No. 3800 Centerpoint Dr. Ste 100 city, Nie, W Anchorage AK 99503 J ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 i Anchorage AK 99503 I I A. kNgnature � E) -,Received b (Primed Name) I C. PW.f D. Is delivery address different from item 0 ❑ Y s If YES, enter delivery address below: ❑ No I (S�Ivice Type rtified Mail 11 Express Mail ❑ Registered C:fReturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes I 2. Article Number (Transfer from service label) ?005 1820 0001 2499 6 019 PS Form 3811, February 2004 Domestic Return Receipt 102595•02•M-1540 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... BIRCH HILL 165-001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY B-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13 W SM FEE-CIRI GRANITE PT 196-045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T 10 N R 12W SM ADL0018761 196-013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4/22/2006 2427 FNL 1303 FWL Sec 13 T 10 N R 12W SM ADL0018761 197-145-0 50-733-20479-00-00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T 10 N R 12W SM ADL0374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T 10 N R 12W SM ADL0018761 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T 10 N R 12W SM ADL0018742 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL' Sec 31 T 11 N R 11 W SM ADL0018742 178-096-0 50-733-20119-00-00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11 W SM ADL0018742 179-017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11 N R 11 W SM ADL0018742 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T 10 N R 12W SM ADL0018742 MCARTHUR RIVER 169-095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8 N R 13 W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13 W SM ADL0017594 SWANSON RIVER 199-055-0 50-133-20489-00-00 SOLDOTNA CK UNIT 2436-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7 N R 9 W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7 N R 9 W SM FEDA028997 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 426-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7 N R 9 W SM FEDA028996 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9 W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWL Sec 22 T 8 N R 9 W SM FEDA028406 172-007-0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 FWL Sec 4 T 7N R 9W SM FEDA028399 162-030-0 50-133-10143-01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9 W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8 N R 9W SM FEDA028406 Wednesday, January 14, 2009 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY STA-20RD SUSP 4/23/1990 1604 FSL 559 FEL Sec 4 T 9 N R 13 W SM ADL0018731 Wednesday, January 74, 2009 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL( Jim Harrison Drilling Manager O7/22/O2 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn' Re: Commissioner Cammy Taylor Report of Sundry Well Operations (Form 10-404) King Salmon, Well K-17 McArthur River Field Commissioner Taylor: Enclosed for your review is a Report of Sundry Well Operations (Form 10-404) for the unsuccessful workover and suspension of King Salmon Well #K-17. We successfully added G-zone perforations, installed the 600 hp electrical submersible pump (ESP), and released the well to Production on April 6, 2002. However, the ESP developed a downhole electrical short two days later on April 8, 2002, and the rig was skidded back over Well K-17 to repair/replace the failed ESP on April 18, 2002. As you are already aware, we had a well control incident which resulted in a fire and injuries during this repair attempt on April 20, 2002. The well has been secured downhole and shut-in since the end of April, pending further evaluation. This matter has been discussed in detail with Tom Maunder. If there are any questions concerning the attached form 10-404, or if additional information is required, please contact me at 263-7809 or Jerry Bowen at 263-7640. RECEIVED JUL 26 2002 Alaska 0il & G~s i.;om; ~.,~;~.~.~.,,,. AOGCC cover letter403.doc Tim Billingsley STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: X Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: Install ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 100' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 694' FSL & 83' FEL of Sec.17, T9N, R13W, SM King Salmon K-17 At top of productive interval 9. Permit number/approval number 1609' FSL & 1073' FEL of Sec 21, T9N, R13W, SM PTD 173-001 / 302-075/302-144 At effective depth 10. APl number 1210' FSL & 962' FEL of Sec 21, T9N, R13W, SM 50- 733-20248 At total depth 11. Field/Pool McArthur River Field 1209' FSL & 905' FEL of Sec 21, T9N, R13W, SM (3 Zone and Hemlock 12. Present well condition summary Total depth: measured 12,120 feet Plugs (measured) CIBP @ 11,800', EZSV @ 7018', Fast Drill @ 6980' true vertical 9,782 feet WRP plug @ 2501' Effective depth: measured 12025 feet Junk (measured) 11,302' (perf gun debris on top of isolation packer) true vertical 9713 feet 2501' portion of WL setting tool on top of WRP plug Casing Length Size Cemented Measured depth True vertical depth Structural Conductor S u trace 2149' 13-3/8" 1750 sx circ to surf 2183' 2031' Intermediate Production 12,062' 9-5/8" 800 sx Class G 12,096' 9764' Liner Perforation depth: measured 10,890 - 10,910'; 10,928' - 10,948'; 10,990 - 11,010'; 11,030 - 11,090'; 11,420 - 11,460'; 11,482 - 11,540'; 11,552 -. 11,774'; 11,856 - 11,876'*; 11,920 - 11,975' true vertical 8,839 - 8,853'; 8,867 - 8,882'; 8,913 - 8,927'; 8,942 - 8,987'; 9,234 - 9,265'; 9,283 - 9,328'; 9,359 - 9,512'; 9,576 - 9,592'*; 9,626 - 9,669' (* squeezed perfs) Tubing (size, grade, and measured depth) 4-1/2" 12.6#, N-80 dropped in well. Top of fish @ 8013' MD, bottom of ESP @ 11,800' Packers and SSSV (type and measured depth) 9 5/8" Otis 'WD' packer @ 11,302', 9 5/8" Otis 'WD' Isolation packer @ 11,882', 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Averaqe Production or Iniection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7-30-01 200 350 5,000 1,200 131 Subsequent to operation 5/1/2002 Well shut-in pending further reeview 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: N/A Daily Report of Well Operations: X Oil: Gas: ~sl~n,~d~ ,~,, !=- ~Service: 17.1 hereby certify that the foregoing is true and correct to the best of my knowledge: ~ ~ L .~~ V~,. L~ "" 2 6 2002 Signed: Jim Harrison Title: Drilling Manager Date: Form 10-404 Rev 06/15/88 JUL s o 2oo2 SUBMIT IN DUPLICATE Date 3/24/02 3/25/02 3/26/02 3/27/02 3/2802 3/29/02 3/30/02 3/31/02 4/1/02 4/2/01 4/3/02 Daily Report of Well Operations King Salmon Well K-17 Workover to Convert Well from Gas Lift to ESP AFE #149271 Summary Switched to K-17 AFE at 22:00 hrs on 3/24/02. PJSM for moving rig. Conducted H2S drill & inspected safety equipment. Repaired SE jacking pad. Skidded rig over K-17. Conducted 2na H2S drill. RU & tested lines to wellhead. Bullheaded well dead w/86 bbls 3%KC1-FIW down tbg & 315 bbls down csg, well on vacuum. Set BPV & ND X-mas tree. Started NU BOPE. NU BOPE & tested same to 250/5000 psi. Tested annular to 250/3000 psi. Repaired accumulator bypass valve. Pump additional 15 bbls 3% KC1-FIW down tbg, on vacuum. Recovered BPV. Un-landed completion & attempted to un-seat pkr, unsuccessful. RU E-line unit. RIH & chemical cut 4 lA" tubing at 11,285'. RD E-line. Started POH L/D 4 lA" tbg. Continued L/D 4 ¥2" tbg. Last 120joints had moderate to severe corrosion. Tested blind rams. P/U overshot fishing BHA. SD to repair Hawkjaw. Finished repairing Hawkjaw. RIH w/fishing BHA & engaged tbg stub at 11,285' DPM. Jarred seals out of pkr. POH & L/D seal assembly. M/U pkr milling BHA & SIH. FIH w/pkr milling BHA. Spotted 40 bbl HEC pill above pkr. Monitored well, losing 39 BPH. Spotted 2na HEC pill, losses decreased to 45 BPH. Milled pkr loose. Pumped Hi-Vis sweep to recover loose pkr rubber, etc.. RIH & pushed pkr downhole to 11,852' DPM, tagged top of isolation pkr. Pumped 40 bbl H-Vis sweep. POH w/5 stands. Observed flowing at low rate. Closed annular, no pressure. Checked for flow, none. Checked for gas, none detected w/hand held detector. Circulated bottoms up, no hydrocarbons, no flow, well stable. Continued POH to 8005', well started flowing +/- 4 BPH. Increased brine weight to 8.8 ppg as precautionary measure. Circulated through choke while increasing brine weight, no hydrocarbons observed, well dead after pumping 164 bbls. SWI, no pressure observed. Loss rate +/- 1 BPH. Finished POH. RU E-line unit. RIH & set CIBP at 11,800'. POH & RD E-line. RU to run TCP guns. M/U guns. RIH to 3236', Fast-Fill valve closed late. POH to 1950' Continued RIH w/TCP guns to 11,126' DPM. RU E-line. RIH & correlate gun depth. RD E-line. Set pkr. Pressured annulus to 1500 psi, perforated 10,890 - 910'; 10,928- 948'; 10,990-11,010'; 11,030 - 11,090' DIL SITP 75 psi. Bled annulus pressure to 500 psi. Opened bypass & circulated 1 lA tbg volumes. Annulus flowing low rate, with occasional gas bubbles. Increased brine weight to 8.8 ppg, closed annular & circulated well through choke. Well dead, drinking 5-6 BPH. POH w/TCP gun. PJSM. L/D gun. RU ESP handling equipment & tbg running equipment. 4/4/02 Finished RU to run ESP. M/U 600 hp ESP assembly. RIH w/ESP to 5300'. 4/5/02 4/6/02 Continued RIH w/ESP on new 4 ½" tbg to 10,755'. Landed tbg hanger. ND BOPS. Started NU X-mas tree. NU X-mas tree. Tested tree and hanger to 5000 psi. Prepared to skid rig over K-20. Turned well over to production at 5:00 hrs on 4/6/02. The rig worked on well K-20 from 4/6/02 to 4/18/02. The following events occurred during that period of time: 4/7/02 ESP production initiated. Had three shut downs for various electrical & de-bugging reasons. 4/8~02 After approximately 12 hours combined total run time, the ESP suffered an electrical fault downhole and could not be re-started. Conductivity checks indicated possible shallow failure of cable or penetrator below wellhead. 4/9101 Loaded well w/8.82 ppg 6% KC1-FIW in anticipation of skidding rig back over K-17 on +1- 4/12/02. Rig work on Well K-17 resumed on 4/18/02. 4/18/02 Prepared to skid rig over K-17 starting at 2:00 hrs on 4/18/02. Skidded rig. RU & tested lines to X-mas tree. Circulated well dead w/436 bbls 6% KC1-FIW. Final rate of losses while circulating was 50%. Installed BPV. ND X-mas tree. Started NU BOPE. ~19~2 NU BOPE. Tested BOPE to 250/3000 psi. Had 200 psi SICP, bled to 26 psi, observed gradual increase to 45 psi. 0 psi SITP. Recovered BPV. Circ well w/343 bbls 6% KC1- FIW. Well dead. Un-landed hanger Inspected BIW penetrator for electrical failure, no damage. Proceeded to POH standing tbg in derrick, pumping in 10 bbls/hr 6% KCI-FIW (approximately double pipe displacement) while POH. 4/20/02 POH w/4 ~A" tbg, spooling ESP cable to approximately 3787'. Cut ESP cable & continued POH approximately 200 additional feet. SD to repair cable spooler. Had high gas alarm on rig floor. Pumped 60 bbls 6% KCI-FIW down annulus, annulus full. Pumped 40 bbls down tbg & had gas/oil at rotary table. Started to close annular, crew initiated cutting of ESP cable using electrical saw and flash fire resulted. Evacuated non-essential personnel and extinguished fire. Found 4 V2" tubing parted at rotary table during fire. Manually closed blind rams & initiated water injection into well via fire pumps. Had small amount of leakage through blind rams. Periodically bled small amounts of SIWHP (gas) to poor boy gas buster. 4121/02 Continued working to secure well & platform. Continued injecting fire water into well and periodic venting of trapped gas to gas buster. Began clearing damaged equipment away from rig floor and wellhead area. Began back loading non-essential equipment to make room for essential equipment. 4./2~02 Continued clearing hazards from work area. Off-loaded BOP equipment. Built scaffolding. Removed bell nipple. Installed riser & 11" 5m single gate BOP w/blind rams on top of damaged existing stack. RU explosion proof lighting around rig floor. Started work to pump 100 bbls of crude oil out of rig pits. Off-loaded & spotted DIS pumping equipment. 4/23/02 4/24/02 4/25/02 4/26/02 4/27/02 4/28/02 4/29/02 4/30/02 Finished hooking up & closing single gate BOP. Re-tightened original stack bolts. Off- loaded mud products & mixed kill fluids. PJSM. Bullheaded 75 bbls 10 ppg CaCO3 LCM pill, followed by 650 bbls 9.5 ppg brine. SD when pressure increased to pre- determined limit of 500psi. RU E-line to set EZSV. Finish RU E-line unit & lubricator. Equalize pressure & open blind rams. Set EZSV at 7018' WLM. Tested EZSV & casing to 500 psi, okay. RIH & set Fast-Drill BP @ 6980' WLM. RD lubricator. Installed night cap. Loaded boats, cleaned decks & cellar. Displaced live oil out of wellbore & replaced w/9.5 ppg brine in stages. Continued displacing live oil out of wellbore & replaced w/9.5 ppg brine in stages & gradually bled trapped SIWHP to 0 psi. Open well & observe dead for 1 hr. ND 11" 5m single gate BOP. Change of plans. NU 11" 5m single gate BOP & E-line unit. RIH & set WRP retrievable BP at 2501' ELM, left portion of setting tool (fish) in well on top of WLM plug. RD E-line unit. Removed fire damaged doghouse, choke~cill lines, & various damaged equipment. ND 11" 5m single gate BOP. Observed annular element protruding into wellbore. ND annular, P/U annular w./chainfalls connected to underside of derrick, skid rig 7' & set annular on stump. Skid derrick 7' back over K-17. Installed tbg hanger with pup joint & Cameron BPV in tbg head. Tightened lock down pins & pressure tested hanger seals, okay. Moved annular from cellar onto drill deck & covered w/plastic. ND & PFLI double BOP using chainfalls, skidded rig 7', set BOP on stump & skidded back over well. Moved BOP ono drill deck & covered w/plastic. ND riser. NU X-mas tree. Tested tree & hanger seals to 5000 psi, okay. RU & tested 9 5/8" casing above WRP plug to 1000 psi, okay. Back- loaded mud products. Cleaned & back-loaded materials & equipment. De-activated rig. Greased valves & filled w/hydraulic oil. Emptied & cleaned pits. Loaded out D/S equipment. Power washed shakers, floor grating, annular & BOPs. Conducted full derrick inspection. Continued cleaning & de-activating rig. Cleaned & pickled mud pumps. PJSM. L/D 213 jts 4 ½" tbg from derrick. Back-loaded all remaining well equipment Switched to De-activation AFE. FINAL REPORT for well K-17. UNOCALe Kibe, Salmon Platform Well # K-17 Completion AO 5/1/02 I~=100' AM~ Topd'fisb K-17 Schem 5-22-02.doc SiZE CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 13 61 K-55 BTC 12.415 Surf 9-5/8 40.0 RS -95 BTC 8.835 Surf 9-5/8 43.5 RS-95 BTC 8.755 7,031' Tubing: 4-1/2" 12.6# L-80 IBTC 3.958 Surf 3-1/2" 9.2 L-80 8rd EUE 2.992 11887' 2183' 7,031' 12,096' 10,654' 11909' JEWELRY DETAIL Top Btm ID Item 33.7 3.958 UH-TC-1AEN 12" x 4-1/2" FMC IBTC top/bot Tbg Hngr w/control line ports plugged & 4 ½" IBTC pin x pin nipple w/3" type 'H' BPV installed 1 jt. of 4 ½" tbg hanging below hanger for weight 11,882 5.0" Otis 'WD' Perm Isolation packer 11,897 2.750" Camco 'D' Nipple 11,909 2.992" Otis 3 ½" WLEG (E.O.T.) 11,852 N/A Otis 'WD' pkr, 20.6' SB ext., Camco 4 ½" DB-6 nipple, 4 ½" WLEG, milled loose & pushed to bottom FISH #1: Otis 'WO' pkr, 20.6' SB ext., Camco 4 ½' DB-6 nipple, 4 ½" WLEG, milled loose & pushed to bottom (above isolation packer) (3/31/2002) Top of fish tagged ~ 11,852' MD FISH #2:600 HP 725 Series HC12000 ESP Assembly, 4 ½" L-80 AB Mod IBTC tbg, 3 SFO-2 SPMs & +/-3700' ESP cable on top of CIBP ~ 11,800' (4/20/02) Top of fish ~ +/-8013' MD PERFORATION DATA Zone Top Btm Amt Comment G-2 10,890' 10,910' 20' G-2 10,928' 10,948' 20' G-3 10,990' 11,010' 20' G-4 11,030' 11,090' 60' HB-1 11,420' 11,460' 40' HB-2 11,482' 11,540' 58' HB-2 11,552' 11,592' 40' HB-3 11,592' 11,655' 63' HB-4 11,655' 11,774' 119' HB-5 11,856' 11,876' 20' SQZD HB-6 11920 11975 55' Revised By JFB Date: 5/1/02 ~KA OIL AND GAS CONSERYA~I~ION COP~ISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Pierce Vice President Unocal PO Box 196247 Anchorage, AK 99519'6247 May 8, 2002 Dear Mr. Pierce: During the aftemoon of April 20, 2002, a well control problem was experienced on the King Salmon Platform (King) while conducting a workover to replace a failed electric submersible pump on well K-17 (PTD 173-001). It appears that accumulated hydrocarbon vapors ignited, resulting in four (4) contract employees being injured and substantial damage to the drilling rig. The Commission was promptly notified by Don Byme and Jim Mosley and was subsequently kept informed while work was planned and initiated to restore control of the well. On April 25, 2002 Unocal submitted a letter providing a preliminary report of an uncontrolled release of hydrocarbon as required by 20 AAC 25.205 (b). In that notice Unocal stated that the final report would be submitted with 30 days of the incident as "required by the regulation. The workover operation on K-17 was subject to Commission regulatory requirements including the following: 20 AAC 25.280 20 AAC 25.285 20 AAC 25.033 20 AAC 25.066 20 AAC 25.070 20 AAC 25.526 20 AAC 25.527 Workover Operations Secondary Well Control for Tubing Workover...BOP Primary Well Control...Drilling Fluid Program and System Gas Detection Records and Reports Conduct of Operations General Well Control Requirements for...Workover... The Commission is keenly interested in understanding the chain of events that led to the loss of well control during the K-17 workover. In order to allow a timely and K-17 (PTD 173-001) May 8, 2002 Page 2 of 2 independent assessment of. the activities on board King while conducting operations on K-17 the Commission requests that Unocal provide us copies of the following documents 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) K- 17 Moming reports Drilling Foremen's Notes (Tally book) Toolpushers' notes (Tally Book) Drillers' notes (Tally Book) IADC tower sheets Productions PLC records Production Operators' notes (Tally Book) Well plan for the workover Contingency plan for kick while tripping with cable through rotary Centrilift hands notes Hole fill or trip sheet The time period covered by the requested documents should begin with the rig move to K-17 and continue, at a minimum on April 20, 2002 at 2400 hours. We would appreciate receiving this material on or before May 20, 2002. Thank you for your cooperation. Thomas E. Maunder, PE Sr. Petroleum Engineer TEM\jjc Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe) Dale Haines Drilling Manager Wednesday, April 24, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Commissioner CammyTaylor Re: Notification of an Uncontrolled Release of Hydrocarbons Trading Bay Unit King Salmon Platform, Well K-17 Commissioner Taylor: This is to inform you that there was an uncontrolled release of hydrocarbons and a resulting fire during recent workover operations on the King Salmon Well K-17. Pursuant to AOGCC Regulation 20 AAC 25.205, the following is a preliminary written report of the incident and ongoing activities: During workover operations to pull an electric submersible pump on 4-1/2" tubing a high gas alarm sounded. At 15:35 hrs. On Saturday, April 20, 2002 a gain was noted and gas vapors were observed coming from the well. Circulation was initiated and while closing the blow out preventors hydrocarbons encountered an ignition source and a fire ensued. The response teams responded to the fire located on and below the drill floor. The platform was shut down and non essential personnel were evacuated from the facility. The fire was extinguished by 16:20 hours and efforts to ensure wellbore integrity and to assess the situation were undertaken. The Unocal Incident Command System was activated to manage the incident. Further inspection of the well revealed that the tubing had parted and fallen down hole. A small leak was identified in the blind rams. There was no spill into the water associated with the hydrocarbon release. The actual volume of hydrocarbons released is being estimated by the accident investigation team. The final values will included in the final written report. RECEIVED 2002 ORIGINAL Alaska Oil & Gas Cons, C0mmissi0r~ Anchorage Alaska Oil and Gas Conservation Commission Notification of an Uncontrolled Release of Gas King Salmon Platform, Well K-17 Page 2 The plan forward for securing the well consists of pumping lost circulation material followed by kill weight brine. A 9-5~8" bridge plug will then be set and tested followed by a second bridge plug which will again be tested. A tubing hanger and back pressure valve will be set in the wellhead and a tree installed upon removal of the blow out preventors. A comprehensive incident investigation is ongoing which should identify the immediate cause of this incident and recommendations for modifying future operations to prevent the reoccurrence of future incidents of this type. Unocal contacted Tom Maunder shortly after the occurrence of the incident on Saturday afternoon and have endeavored to keep him informed. As required by AOGCC Regulation 20 AAC 25.205, a detailed written program will be submitted within 30 days of the incident. Please contact me at (907) 263-7951 if any more information or clarification is required. DH/lb Sincerely, Drilling Manager Unocal Alaska ORISIN/ ,L STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION CtJMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: x Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 694' FSL & 83' FEL of Sec. 17, T9N, R13W, SM King Salmon K-17 At top of productive interval 9. Permit number 1609' FSL & 1073' FEL of Sec. 21, T9N, R13W, SM 173-001 ""'"' At effective depth 10. APl number 1210' FSL & 962' FEL of Sec. 21, T9N, R13W, SM 50- 733-20248 At total depth 11. Field/Pool 1209' FSL & 905' FEL of Sec. 21, T9N, R13W, SM McArthur River/Hemlock Pool 12. Present well condition summary Total depth: measured 12,120 feet ~,4 Plugs (measured) true vertical 9,782 feet v"' Effective depth: measured feet Junk (measured) 11,302' (perf gun debris on top of isolation plug) true vertical feet 8,013' (4-1/2" tubing fish) Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2149' 13-318" 1750 sx circ to surf 2183' 2031' Intermediate Production 12,062' 9-5/8" 800 sx Class G 12,096' 9764' Liner Perforation depth: measured 10,890' - 10,910'; 10,928' - 10948', 10990' - 11010', 11,030' - 11,090'; 11,420 - 11,460'; 11,482' - 11,540'; 11,552 - 11,774'; 11,856 - 11,876'*; true vertical 8847' - 8853'; 8866'- 8881'; 8912' - 8927'; 8942' - 8986' 9,234 - 9,265'; 9,283 - 9,328'; 9,359 - 9512'; 9576 - 9592'* (* squeeze perfs) Tubing (size, grade, and measured depth) 4-1/2", 12.6~, N-80 @ 11,344' Packers and SSSV (type and measured depth) 9-5~8" Otis 'WD' packer @ 11,302' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 4~23~2002 16. If proposal well verbally ap, Bro..ved: Oil: X Gas: Suspended: Tom Maunder ~:1~(~ ~Y"'~ I'~ ~,),~ 4/23/02 Name of approver Date approved Service: 17.1 herebp/-,ce,.rtifyl~ I"~ ~ ~l)//~//~J~ ~/J ~\that-tl~ foregoing~i,s true and correct to the best of my knowledge. ¢--/~_~_ Sig nea.,W~q~.~t ¥.[ ~j,l~g/[ L//t. ~Y~ale Haines Title: Drilling Manager Date: .... v, FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness /Approval No. . Plug integrity BOP Test Location clearance _["~ ~~ r r*t '~.¢~- Mechanical Integrity Test Subsequent form required 10- t-l~(~ Original S4gned Alaska 0,, & Gas Cons, Gammy Oech~ T~ Anchora0e Approved by order of the Commissioner Commissioner Date . . Form 10-403 Rev 06/15/88 ORIGINAL ? SUBMIT IN TRIPLICATE UNOCAL o . , . o . . 1 , ]~. ag Salmon Platform Well # K-17 Procedure To Secure Well Inspect all equipment to access damage, identify current safety hazards, identify equipment needed to safely conduct following procedure & determine safe action plan. Hook up high pressure hose from choke line to gas buster. Vent SI gas to gas buster to minimize leakage through blind rams. Continue to vent gas as long as rate and pressure are Iow. Back load non-essential equipment to clear deck space. Secure traveling block with block hanging line. Release brake & lower block. Pull away from rotary table with come-along & mark off area below block. Remove bell nipple, clean & inspect stud holes on top of annular. Rig up Dowell cement pump(s) to pump Kill Weight Fluid down casing. Flange up 11'- 13 5~8" 5m spool, 13 5~8" 5m x 11" 5m adapter spool, 11" 5m mud cross, 11" 5m Shaffer single BOP (wi blind rams). Install cap on BOP until ready to RU lubricator. Bullhead kill well following the following pumping schedule: a. Pump 75 bbls 9.9 ppg NaCL brine at 3-4 bpm from batch mixing tank. b. Pump 75 bbls 10.0 ppg CaCO2 LCM pill at 3-4 bpm (mixed in pill pit and and transferred to DS displacement tanks. c. Pump a maximum of 752 bbls 9.5 ppg KCL/NaCI brine at 3-4 bpm on the fly. RU Schlumberger and E-line lubricator w/9 5~8" EZSV inside. Test lubricator to 500 psi. Open the Rams using accumulator (or with the DS pumps if necessary). RIH and set EZSV bridge plug at +/- '7000' MD (top of ESP fish should be at +/- 8013'). Close 11" BOP. Pressure test casing & EZSV to 500 psi for 30 minutes. Bleed off pressure to production (estimate fluid returns if possible and the time to bleed off). Fill hole with 9.5 ppg KCL/NaCI brine. RIH & set Ceramic Bridge Plug at +/-7000 or just above the first plug'. RD E-line unit & lubricator. 10. ND 11" BOP & 13 5/8" x 11" adapter spool. K-17 AOGCC Permit Program. DOC Page 1 of 2 4/23/02 UNOCAL ) · .~g Salmon Platform Well # K-17 Procedure To Secure Well 11. M/U FMC 4-1/2" tbg hanger (4-1/2" BTC threads top) with 4-1/2" BTC nipple made up on the bottom. The nipple will have a 3" CIW Type 'H' BPV profile cut into it. Drain stack to verify proper setting, and set tbg hanger in tbg head. Tighten tie-downs. Pressure test thru casing annulus valve to 1000 psi 30 minutes. 12. Install the new bridge crane support bracing for handling the BOPE. 13. N/D BOP Stack and Riser. N/U Tree using the clamp currently on the drilling riser. Test tree to 1500 psi. K-17 AOGCC Permit Program. DOC Page 2 of 2 4/23/02 UNOCALe King oalmon Platform Well # K-17 Proposed Abandonment RKB to TBG Hgr = 33.75' h. 2183' 13 3/8" 7000' Bridge Plug 7,018' Bridge Plug 8,013'+/- TOF SIZE 13 9-5/8 9-5/8 WT CASING DETAIL GRADE CONN ID TOP 61 K-55 BTC 12.415 Surf 40.0 RS-95 BTC 8.835 Surf 43.5 RS-95 BTC 8.755 7,031' BTM. 2183' 7,031' 12,096' G-2,3,4 HB-1,2,3,4 HB-5 Sqzd HB-6 9 5/8" csg PBTD -- 12,025' TD = 12,120' Max HOLE ANGLE - 44° @ 3800' PERFORATION DATA Zone Top Btm Amt Comment G-2 10,890' 10,910' 20' G-2 10,928' 10,948' 20' G-3 10,990' 11,010' 20' G-4 11,030' 11,090' 60' HB-1 11,420' 11,460' 40' HB-2 11,482' 11,540' 58' HB~ 11,552' 11,592' 40' HB-3 11,592' 11,655' 63' HB-4 11,655' 11,774' 119' K- 17 403 Abandonment Schematic.doc Revised By LWB ,April 20, 2002 1600 Call from Lou that King Salmon is on fire. 1605 Call from Don Byrne... on his way in... had been notified by Jim Mosley of an incident on King... appears to be well related.., they are on K-17RD 1610 Attempt to contact Dan... left message with Barb 1611 Call Cammy and leave message.., get cell phone number from Linda. .. finish talking to Cammy at 1625. In the interim.., call from Jim Moseley... apparently tded to cut the ESP cable with an electric saw and there was a flash.., unknown if the fire was out.., well SI on annular with ESP cable through it. 1630 Talk to Jerry on XTO C... fire appears contained.., smoke dissipating.., passed information to Cammy. 1632 Call from Jeff...just ran down to the bluff.., smoke was rolling off.., dropped off 1 non-critical at heliport and flew off to the hospital with the critical person...fire apparently on the drill floor Listened to Jeff's message 1641 Call from Lou... brief him on what information Jeff had Talk to Cammy... she came in ' 1705 SD and depart. , ................................... April 22, 2002 0820 Arrive at office,,, copy and distribute faxes from UnOcal. "' ' 1620 Return Dan VVilliamson's call.., talk to Jim Mosley... odginal BR are still shut.,, little bit of pressure under them.., tries to bubble every now and then,., continuing to intermittently flood the backside and bleed off.., working between 85 and 60 psi... ND the bell nipple and installed a riser on top of hydril with a flow cross and BR on top.., plan forward is to flange up to the new BR... RU Dowell under lower blinds and perform a top kill,., following that they will SOS and set a plug as deep as possible.., projected to be about 7000'... ND preventers and NU tree,., commence to work on rig Presently bleeding about once per hour,., planning to kill with Dowell tomorrow.., unknown if they can pump from pits to drill deck.., platform generators are presently not back up...will have to figure a way to get fluid to the pumps Apdi 23, 2002 1240 Return call to Jim Mosley... have a WRP bridge plug.., located plug.., expect 2 - 3 months minimum to get rig back together.. . well is presently SI with the new set of BP, since early this morning.., presently planning to do the kill.,, presently have 210 psi,.. KW fluid calculates to 8.8 or 8.9...will ND blind flange on top BR and NU full shooting nipple... BP will hold pressure from above and below.., tubing retrievable.., expect to get to 7000' 1245 Call from John and Chuck on the slope.. . discuss King... pull file and diSCuss ' ' ' April 24, 2002 1008 Call Jim Mosley and Larry Buster... have pumped 725 bbl kill weight fluid into the hole including LCM pill.. . weight of fluid 9.9 followed by 10.0 LCM followed by 9.5 ppg brine.., max injection pressure 400 psi...when LCM hit.., staged up to 500 psi 7 times and SD to observe.., subsequent, picked up EZSV... RIH and set at 7018'... did not tag and fish.., plug has been tested to 500 psi with no bleed off.., presently resting crews and observing well.., plan to bleed off any gas and test again.., then set another EZSV around 3000'... surface casing shoe is at 3100... OSHA and Unocal team might go out today... Inspector likely can go out tomorrow. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe) Dan Williamson Drilling Manager O2/2O/O2 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Application for Sundry Approvals (Form 10-403) King Salmon, Well K-17 McArthur River Field Commissioner Heusser: Enclosed for your review is an Application for Sundry Approval (Form 10-403) for the planned workover to install an electric submersible pump (ESP) in King Salmon Well #K-17. It is our intention to abandon the HB-6 perforations and add new perforations in G-2,3,4 Sands during the workover, after the tubing is recovered from the well. Because we are adding perforations, we will invalidate our existing No-Flow Test during the workover. However, based on our experience with the lower pressured G-zone in the Cook Inlet, we are confident that the well will pass a No-Flow Test within a few weeks after the well is on ESP production. Therefore, Unocal respectfully requests a temporary waiver of AOGC regulation 20 AAC 25.265, to avoid the unnecessary expense of running a packer or a SSSV with the ESP completion. This matter has been discussed in detail with Tom Maunder. If there are any questions, or if additional information is required, please contact Jerry Bowen at 263-7640. Dan Williamson Drilling Manager RECEIVED FEB 2 5 200 Alaska 0il & Gas Cons. Commission Anchorage AOGCC cover letter403.doc ORIGINAL Tim Billingsley APPLICATION FOR SUNDRY APPROVALS · STATE OF ALASKA /o ' ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: Install ESP 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface ~'¥ 8. Well number 694' FSL & 83' FEL of Sec,~, T9N, R13W, SM King Salmon K-17 At top of productive interval 9. Permit number 1609' FSL & 1073' FEL of Sec 21, TSN, R13W, SM '~J~-l'~ [t"t'~ - At effective depth 10. APl number 1210' FSL & 962' FEL of Sec 21, T9N, R13W, SM 50-"~33-20248 At total depth 11. Field/Pool 1209' FSL & 905' FEL of Sec 21, T9N, R13W, SM McArthur River/Hemlock Pool 12. Present well condition summary v/ Total depth: measured 12,120 feet Plugs (measured) None true vertical 9,782 '~ feet Effective depth: measured ## feet Junk (measured) 11,302' (perf gun debris on top of isolation packer) true vertical ## feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2149' 13-3/8" 1750 sx circ to surf 2183' 2031' Intermediate Production 12,062' 9-5/8" 800 sx Class G 12,096' 9764' Liner~ .~.~ Perforation depth: measured 11,420 - 11,460'; 11,482 - 11,540'; 11,552 - 11,774'; 11,856 - 11,876'*; ~ . 11,920- 11,975' true vertical 9,234- 9,265'; 9,283 - 9,328'; 9,359 - 9,512'; 9,576 - 9,592'*; 9,626- 9,669' ~ N (* squeezed perfs) Tubing (size, grade, and measured depth) 4-1/2" 12.6#, N-80 @ 11,344' Packers and SSSV (type and measured depth) 9 5/8" Otis 'WD' packer @ 11,302', 9 5/8" Otis 'WD' Isolation packer @ 11,88 4-1/2" Camco TRDP-1A tubing retrievable SSSV @ 390'_ . L'~ ~_ 13. Attachments Description summary of proposal: x Detailed operations program: BOP sketch: ~ Current & Proposed Wellbore Schemeatics: ~ 14. Estimated date for commencing operation 15. Status of well classification as: 4/2/2002 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby/~rtify tha[,thej ~f~oing is true and correct to the best of my knowledge. Signed.~ ~.,~/~~illiam~n Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represe~.n~ative may witness ~:~)(~)~ ~)~1'~) ~::;~..~.~'~'' IAppr°val'.~ Plug integrity.__ BOP Test ~ Location clearance__ Mechanical Integrity Test. ! S'ubsequelr~form required 10- t.~ O ~-~ ORIGINAL $tGNE[._~ F~¥' Approved by order of the Commissioner ] ~ ~,~.~ Commissioner Date . . Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE K- 1 RD2 ESP Conversion Workover No. Procedure Summary 1 Shut-off gas lii~ & bleed SICP to 0 psi (immediately prior to skidding) 2 Skid rig over K-17 (Load well w/3%KC1-FIW while skidding) 3 Bleed any trapped pressure, top off w/3%KC1-FIW & verify well dead 4 Install BPV 5 ND tree/flowline 6 Inspect hanger threads & pressurize SSSV control line 7 NU BOPE 8 Recover BPV, install TWC valve & test blind rams to 3000 psi 9 Recover TWC valve & engage hanger with landing joint 10 Test pipe rams, choke/kill lines & accumulator to 3000 psi 11 RU to pull tubing 12 Back out hold down pins, attempt to pull seals from pkr 13 RU APRS, cut tbg above packer, & RD APRS ., 14 POH & L/D corroded/scaled 4 1/2" tubing (assume string is not re-usable) 15 RIH w/oveshot & engage tbg stub 16 Release tbg stub & POH 17 RIH w/mill, mill packer loose & POH 18 RIH w/spear, engage packer & POH 19 RU E-line, set CIBP & dump cement above HB-5 20 Perforate G-2,3,4 (120' net) & RD E-line unit 21 PU required amount of new 4 1/2" tubing & stand in derrick 22 RU to run ESP 23 PU 600 hp ESP assembly w/725 series motor & Phoenix sensor 24 MU XO on pump, splice cable and chem inj lines 25 RIH with ESP 26 Make splice 27 RIH with ESP 28 Make splice 29 RIH with ESP to 11,280' 30 MU hanger, make splice 31 Land tubing 32 Nipple down BOPE 33 Install & test tree & flowline 34 Prep to skid to next well King Salmon K1RD2 BOP Stack To of Table Btm of Trolly beam 3 1116"5M x 4 1116"5M DSA A 4 1/16" 5M Foster HCR Valve B 4 1116" 5M Manual gate valve C 3 1116" 5M Manual gate Kill line D 3 1116" 5M Manual gate Kill line 13 5/8" 5M t 1.00' 4.90' Top of drill deck 16.00' 12.50' Graylock Hub Top of FMC Type OBS Tubing Head Adapter .,. Alaska, Inc ...... . .... radlng Bay Unit-.King Salm(. ,., .- atfomT Well. 1(:-17 Spud Date." 1-26-73 Original RKB: 100,'MSL. 'top of Hemlock: 114213' Annulus Fluid: Sea' water All Depltm are. RKB MD to Top of Equipment ~ ~0-733-202484Z] Completion Date: 1-25-88 · Hanger Type: FMC 4-1/2' BTC Max Hole Angle: 44° Last Revised: 02-27-90 ...? B-1 B-2 B-3 B-4 B-5 B-6 ] ] I Jowel~ 1 ! 390' 2 11300' 3 11302' 4 113,14' 5 11344' 6 11345' 7 11882' ~12 8 11886' 9 118.97' 10 11g08' 11 11~)9' 14 15 7 8 9 10 11 13 Well Type: Producer New r'l Workover RKB to Hanger: '33.75' Angle at Perforations: 39° Reason: Gauge Ring Data Camc~ TRDP-1A SSSV nipple: ID - 3.812' Seab. Top to Iocator. 1.05' :1:1.00" ,pace-out Otb *WD' perm. pkr. w/5' bore (Iocatcx to bottom) Camco "DB'6* nipple: ID · 3.750' Otis 4-1/2- BI'C WL rc entry guide 4-1/2- tubing tall Otis ~/VD' perm. pkr. w/5' bore (Iocator to bofforn) XO to 3-1/2' EUE 8rd Cameo 'D' nipple: ID Otb 3-1/2- EUE 8rd WL re-enfly guicle 3-1/2' tubing tall 12 13 Cmlng and Tubing 13-3/8' 61~ 9-5/8' 43-1/2~ & 40~ 4-1/2' 12.6~ 3-1/2' K-55 BTC 34' 2183' Ca~lng RS-95 BTC 34' 12096"-Cadng - L-80 ABM-BTC 34" '1'134~" IPC Tubing 8rdBJE 11887' 11909' - bopkrtbgtail 14 ~ Uft Infmlm]tlon 2540" 1 2296' Camco MMG 4166' 2 3510" Camco MMG 5476' '3 4512" Camco MMG 6458" ' 4 5300" Camco MMG 7212" 5 5897* Camco MMG 7723" 6 6300" Camco MMG 8210" 7 6691" Camco MMG 8730' 8 7110" Camco MMG 02i5 9 7534' Camco MMG ~)98'' 10. 7904" Camco MMG 10209' 11 8313' Camco MMG 10726' 12 8710" Camco MMG 11249' 13 9101' Camco MMG Perforation Data. DIL dopths 15 Zone~ ~ FT SPF · 1 11420/9135 11420-11460 40 4-16 2 11472/9178 11482-11540 58 4-12 .11552-11592 40 8 3' 11,9;2/9270 11592-11655 63 4-24 4 11655/9'320 116_~_11774 119 4-24 5 111[O/9435 11856-11876 33 SQZD 6 11915/9522 11920-11975 55 4 7 12028/10010 No Perforatiom Valve Latch Port~ TRO P$C CA, R-20 R K 1/4' 1150 1223 CA, R-20 R K 1/4' 1160 1215 CA, R-20 R K 1/4* 1165 1208 MA, R-20 RK 3/8* 1275 1178 MA, R-20 RK 7/16' 1340 1165 MA, R-20 R K 1/2' 1440 1145 MA, R-20' -' R K 1/2" 1425 1125 MA, R-20 R K 1/2" ORIfiCE MA, R-20 R K DUM DUM MA, R-20 R K DUM DUM MA, R-20 RK DUM DUM MA, R-20 , R K DUM DUM MA, R-20 ~ RK DUM DUM Gauge Ring and Fill Level Data ~ size Death Comment! 9-8-88 2.70' 11886' no go pkr 9-21-88 3.70' 11330' no deeper 12-15-88 EL 11880' no go pkr 1-23-90 3.70' 1130g no deeper 2.70' 11990" tagged fill · · PBTD = 12025' MD · · 1D = 12120' MD Datum= 11696'MD (9350' ~, 9450'~) UNOCAL Kin~, Jalmon Platform Well # K-17 Proposed Completion 2/15/02 RKB to TBG Hgr = 33.75' Hngr. connection: 4-1/2" Butt CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13 61 K-55 BTC 12.415 Surf 2183' 9-5/8 43.5 & 40.0 RS-95 BTC 8.535 Surf 12,096' Tubing: 4-1/2" 12.6# L-80 AB Mod 3.958 Surf 11,200'_+ IBTC 3-1/2" 9.2 L-80 8rd EUE 2.992 11887' 11909' NO. Depth 33.7 3.958 1. 11,200' 3.958 2. N.Y.D. 3.833 3. 11,300' N/A 4. 11302' 5.0" 5. 11897' 2.750" 6. 11,909' 2.992" 7. 11,850' N/A JEWELRY DETAIL ID ltem TC-B-EC 12" x 4-I/2" FMC IBTC top/hot Tbg Hngr 4-1/2" 12.9 ppf L-80 AB Mod IBTC Tbg 4-1/2" GLM #1 SFO-2 (7.063" OD) 600 HP 725 Series HC12000 ESP Otis 'WD' Perm Isolation packer Camco 'D' Nipple Otis 3 ½" WLEG (E.O.T.) CIBP (or Cement Retainer) G-2,3,4 HK-1,2,3,, .5 !HB-5 (SQ ~ 7 ~6~4HB_6 PBTD -- 12,025' TD = 12,120' Max HOLE ANGLE - 44° @ 3800' PERFORATION DATA Zone Top Btm Amt Comment G-2 10,890' 10,910' 20' Proposed G -2 10,928' 10,948' 20' Pro pos ed G-3 10,990' 11,010' 20' Proposed G-4 11,030' 11,090' 60' Proposed HB-1 11,420' 11,460' 40' HB-2 11,482' 11,540' 58' HB-2 11,552' 11,592' 40' HB-3 11,592' 11,655' 63' HB-4 11,655' 11,774' 119' HB-5 11,856' 11,876' 20' SQZD HB-6 11920 11975 55' Fish & Wireline Tag Data Note: Attempted to set 3 ½" blanking plug in Camco 'D' nipple in Jan. 2002. Tagged perf gun debris on top of 'WD' pkr. 1~-17 Prop Schem 2-15-02.doc DRAWN BY: JFB Date: 2/15/02 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Camille O. Taylor, ~ , DATE: Chair Tom Maunder, P. I. Supervisor November 14, 2001 FROM' Lou Grimaldi, Petroleum Inspector SUBJECT' No-Flow Test Unocal Steelhead K-17 McArthur River Field.TBU : PTD ~73,001,' NON-CONFIDENTIAL Wednesday, November 14, 2001' I witnessed a No-Flow verification on UNOCAL's King Salmon platform wells #K17 in the McArthur River field. Following is a timeline and well status during test. 1000 Well flowing at less than 180 scf, no fluid. 1020 Shut-in well 1040 SITP 6 psi 1135 SITP 6 psi, open well to atmosphere. Flow initially less than 180 scf and dropped to bare whisper. 1140 Shut-in well 1310 $1TP 10 psi, Open to atmosphere. Flow initially 1800 scf decreased to less than 180 scf (bare whisper) Note: The gauge used to check flow was incable of measuring below 180 scf or above 2000 scf. This well exhibited inability to flow to surface unassisted and I recommendJt be grantedNo-Flow status. This well is due for a workover during which a ESP will be in,lied. I explained to Mark Atkins (Platform Foreman) that any cleanout, perforating or other stimulation will require anOther No-Flow test. SUMMARY: I witnessed No-Flow verification on UNOCAL's King Salmon platform well #K-17 in the McArthur River field. ,NON-CONFIDENTIAL CC: Dwight Johnson/Mark Atkins (UnOcal) Attachment: None No-Flow UNOCAL TBU K-17 11-14-01 LG.doc Alaska Region Unocal North Americar)--.~, Oil & Gas Division ~ Unocal Corporation P,O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ~'O-MM COMM L_R__E_S ENG , SR ENG SR ENG ENG ASST ENG ASST ~ SR GEOL/~4 -G-'~'E'ASSTI l S AT I !~iLE L..! November 10, 1993 Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Ms. Miller: On July 9, 1991 an Application for Sundry Approval, number 91-198 was approved to perforate well K-17 in the Trading Bay Unit. However, after researching the files, I've found that the work was never done. Sincerely,.~, Ralph P. Holman RECEIVED NOV 1 5 1993 Alaska 0il & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COM~IISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 2767542 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, In' conducting an audit of well files i have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. To be in compliance with AS 20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversations concerning the subject, it had been explained to me that either ARCO or Marathon had been tlT~Ub-operator on the majodty of the w0'rk proposed; however, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application' of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application on file can be marked accordingly. Sincerely,' .1 · · Statistical lechnician ~.~ pfinled on recycled paper -2- Well No. Permit No. Approval Date & No. Description 10-403 Signed By K-17 K-25 M-25 M-28 73-1 85-78 87-86 : 90-19 7-9-91, 91-198 2-9-90, 90-079 7-9-91, 91-201 11-1-91, 91-326 7-30-91, 91-224 8-27-91, 91-252 9-20-91, 91-285 Perforate 6/91 Perforate 2/90 Perforate 6/91 Perf. G/WF intervals & rerun jet pump 10-22-91 Perf. & evaluate BWF potential 7-14-91 Install jet pump, pump-in test 8-15-91. Bagal W/F Refrac 9/91 G. Bush R. Roberts G. Bush G. Bush G. Bush G. Bush G. Bush . · STATE OF ALASKA SSIoN ALASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend'__ Operation Shutdown m Re-enter suspended well m ~"~/~' Alter casing __ Repair well _ Plugging m Time extension _ Stimulate__ Change approved program Pull tubing Variance _ Perforate }( Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Corporation Development .~. 100' KB above MSL feet (ARCO Alaska. Inc. is sub-ooerator) Exploratory _ 13. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Ser~ce Trading Bay Unit 4. Location of well at surface 8. Well number 694' FSL, 83' FEL, Sec. 17, TDN, R13W, SM K-17 At top of productive interval 9. Permit number 1609' FSL, 1073' FEL, Sec. 21, TDN, R13W, SM At effective depth 10. APl number 1210' FSL, 962' FEL, Sec. 21, TDN, R13W, SM _50d 33-20248 _ At total depth 11. Field/Pool 1209' F.SL,.905' FEL, Sec. 21~ TDNr R13w, SM Hemlock .... ,, ,,.. ,-. 12. Present well condition summary K ~ ~ ~' I V Total Depth: measured 1 21 20' feet Plugs (measured) 1 2025' true vertical 9782' feetJUL -9 1991 Effective depth: measured 12025' feet Junk (measured) 11990' true vertical 9 71 3' feet Alaska 0il & Gas Cons. Casing Length Size Cemented Measured depth Tru~'~~epth Structural Conductor Surface 21 4 9' 1 3 - 3 / 8" yes 2183' 2 0 31' Intermediate I 2 0 6 2' 9-5/8" yes 1 2 0 9 6' 9 7 6 4' Production Liner Perforation depth' measured 11420-11460'; 11482-11540'; 11552-11774'; 11856-11876'; 11920-11975' true vertical 9234-9265'; 9283-9328'; 9358-9512'', 9576-9592'' , 9626-9669' Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 BTC @ 11345' MD ; 3-1/2", 9.2#, 8rd EUE fm. 11887-11909' MD Packers and SSSV (type and measured depth) Camco TRDP-1A SSSV @ 390' MD; Otis "WD" pkr ~ 11302' MD; Otis "WD" pkr ~ 11882' MD i3. Attachments Description summary of proposal_ Detailed operation program _,~.. BOP sketch_ Proposed perforations attached. 14. Estimated date for commencing operation 15. Status of well classification as: June. 1991 Oil ;~ Gas .. Suspended 16. If proposal was verbally approved Name of approver Date ,approved Service . , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~.~;~/. .~ /~.~' ~.~. Title ,/~. ,~,',~.~. ./~'~.,rl~- Date c./ '~/ FOR COMI~SION USE O~LY , Conditions of approval: Notify COmmission so representative may witness IApproval No. BOP Test Location clearance ~ I ¢:~ / - ! PlUgMechanicalintegritYlntegrity Test _ -- Subsequent form require 10- ~¢~' / ORIGINAL SIGNED !t¥ Approved Copy / Approved by th,e order of the Commission "] .... Commissioner D_a? __ . Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE SUMMARY OF PROPOSED WELL OPERATIONS WELL TBU K-17 (3une, 1991) 1. RU E-line unit. 2. Perforate the following intervals under draw-down conditions: Run No. Bench Interval (MD.CET~ ~terval (MD-DIll) 1 6 11963-1197 7 11964-11978 2 6 11937-11957 11938-11958 3 6 11919-119 3 7 11920-11938 4 4 11729-11749 11730-11750 5 4 11691-11711 11692-11712 6 4 11659-11679 11660-11680 7 3 11599-11619 11600-11620 Note: 3. Lubricator will be pressure tested to 2500 psig prior to each run. RD E-line unit and lubricator. Leneth SPF 14' 4 20' 4 18' 4 20' 4 20' 4 20' 4 20' 4 132' RECEIVED ,JUL - B lggl ~a$~ Oil.& 6as Cons. ,8ommission ~nehorago E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves · RECEIVED Wellhead d u L - 9 t991 Alaska Oil & Gas Cons. ~ch~ra. ge MOH 6/1/91 Unocal North Ameri¢~--~X. Oil & Gas Division Unocal Comoratlon P.O. Box 1902,t7 Anchorage. AlasKa 99519-02-t7 Teie0none ~90,-'3 2'6-7600 IJNO L Alaska Recj~on 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, G sh ' Regional Drilling Manager GSB/lew APR 2 -', 197 KING SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR LEG #1: LEG #2: 9 l0 ll 12 13 14 15 16 LEG #3: 17 18 19 20 21 22 23 24 Leg #4- 25 26 27 28 29 30 31 32 "Y" COOR. "X" COOR. WELL #' FNL ,, , 2,511,762 2,511,761 2,511,764 2,511,768 2,511,772 2,511,773 2,511,770 2,511,766 2,511,690 2,511,686 2,511,684 2,511,687 2,511,691 2,511,695 2,511,696 2,511,694 2,511,689 2,511,723 2,511,721 2,511,724 2,511,728 2,511,732 2,511,733 2,511,731 2,511,726 2,511,799 2,511,798 2,511,801 2,511,805 2,511,809 2,511,810 2,511,807 2,511,803 213,819 K-21 & RD 688 213,815 K-30 687 213,811 K-18 690 213,810 K-17 694 213,812 K-23 (23-19) 698 213,817 K-19 699 213,821 K-22 & RD 696 213,822 K-20 692 · 213,768 213,772 213,768 213,763 213,762 213,765 213,769 213,776 213,774 213,712 213,708 213,703 213,702 213,705 213,709 ,213,713 213,714 213,760 213,756 213,752 213,751 213,753 213,758 213,762 213,763 FWL 74 78 82 83 81 76 72 71 K-15 & RD 611 121 K-9 610 126 K-4 & RD 613 130 K-Il 617 131 K-13 & RD 621 128 K-2 & RD 622 124 K-7 & RD 619 120 K-5 615 l!9 K-8 725 133 K-1 & RD 724 135 K-10 &'RD 727 !41 K-16 731 142 K-12 & RD 735 140 K-6 & 24 736 135 K-3 & RD 729 130 /'-'"' STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMM,._..,ION 0 REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate w Plugging .. Perforate Pull tubing ... Alter casing Repair well Pull tubing X Other 2. Name of Operator UNOCAL Corporation (ARCO Alaska, Inc. is sub-ooerator) 3. Address P. O. Box 190247, Anchorage, AK 99519 5. Type of Well: Development, Exploratory Stratigraphic Service Location of well at surface 694' FSL, 83' FEL, Sec 17-T9N-R13W-SM At top of productive interval 1609' FSL, 1073' FEL, Sec 21-T9N-R13W-SM At effective depth 1273' FSL, 925' FEL, Sec. 21-T9N-R13W-SM At total depth 1209' FSL, 905' FEL, Sec. 21-T9N-R13W-SM 6. Datum elevation (DF or KB) 100' RKB 7. Unit or Property name Trading Bay Unit 8. Well number K-17 feet 9. Permit number/approval number 73-01/7-~I~0 10. APl number 5o-133-2024800 11. Field/Pool Hemlock 12. Present well condition summary Total Depth: measured true vertical 1 21 20' feet Plugs (measured) None 9782' feet Effective depth: measured 1 2025' feet Junk (measured) None true vertical 9707 feet Casing Length Size Cemented Measured depth Structural Conductor 352' 24" Driven 382' Surface 21 5 3' 1 3 ~ 3 / 8" 1371 sx Class G 21 83' Intermediate Production 1 2 0 6 6' 9 - 5 / 8" 800 SX Class G 1 2 0 9 6' Liner None Perforation depth: measured 11420-11460', 11482-11540', 11552-11774', 11920-11975'. true vertical 9233-9264', 9283-9328', 9338-9517', 9626-9669'. Tubing (size, grade, and measured depth) 4-1/2", L-80 ABM-BTC, 11345' MD, 3-1/2" 8RD EUE, Packers and SSSV (type and measured depth) 11887-11909' MD. True vertical depth 382' 2031' SSSV: Camco TRPD1-A @ 390' MD; Otis "WD" pkr. @ 11302' MD~ Otis "WD" pkr ~ 11882' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation (1 2/29/87) Subsequent to operation (2/3/88) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 536 303 3032 1280 1081 281 3506 1250 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service Tubing Pressure 200 130 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Environmental Analyst Form 10-404 Rev 05/~/§9} ~ Date 1/3/90 SUBMIT IN DUPLICATE WELL TBU K-17 SUMMARY OF WORKOVER OPERATION KING SALMON PLATFORM OBJECTIVE Replaced scaled tubing and gas lift mandrels, re-perforated production zones, and perforated Bench 6 interval. pROCEDURE . . , , , . , , 10. 11. 12. Move rig over well TBU K-17, leg #1, slot #4. Killed well with NaCI brine. ND tree. NU and tested BOPE. Pulled and layed down 4-1/2" tubing string. Milled over and recovered two Baker Model "D" permanent packers set at 11300' MD and 11795' MD inside 9-5/8" casing. Pressure tested integrity of squeezed perforations in Hemlock Bench 5. Pressure tested 9-5/8" casing. OK. Cleaned out to PBTD at 12025' MD. Ran casing inspection log from PBTD to surface. Perforated Hemlock Benches 3,4, and 6 under 500-1000 psi drawdown with 5" drill pipe conveyed guns. Perforated intervals 11600-11650', 11660-11710', 11730- 11770', 11920-11975' DIL-MD. Ran new 4-1/2" tubing completion assembly. ND BOPE. NU tree. RD and moved to next well. STATE OF ALASKA ALAL ,, OIL AND GAS CONSERVATION COry, SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate~[ Pull tubing Aiter Casing [] Other ~ WORKOVER 2. Name of Operator UNOCAL (ARCO Alaska: Inc. is sub-onerator) 3. Address P.0. Box 190247, Anchorage, AK 99519 4. Location of well at surface Leg 1, Conductor 4 694' FSL, 83' FEL, Sec.17, TgN, R13W, SM At top of productive interval 1609' FSL,'1073' FEL, Sec.21, TgN, R13W, SM At effective depth !210' FSL, 962' FEL, Sec.21, TgN, R13W, SM At total depth 1209' FSL~ 905' FEL~ Sec.21~ TgN~ R13W~ 5M 11. Present well condition summary Total depth: measured 12120'MD true vertical 9782 ' TVD Effective depth: measured 12025'MD true vertical 9713'TVD 5. Datum elevation (DF or KB) RKI~ 100, 6. Unit or Property name Trading Bay Unit 7. Well number K-17 (44-21) 8. Approval number 7-flRn 9. APl number , ~50-- 133-202z~R 10. Pool Hemlock & "G" Pool feet Plugs (measured) None feet feet Junk (measured) None feet Feet Casing Length Size CondUctor 352 ' 24" Surface 2153 ' 13-3/8" P roducti on 1.2066 ' 9-5/8" Cemented Measured depth Pile driven 382'MD 1371 sx Class G 2183 'MD 800 sx Class G 12096'MD True Vertical depth 382'TVD 2031'TVD 9764'TVD Perforation depth: measured 11420'-11460 ' 11600'-11650' true vertica~ 9233 '-9264 ', 9283 '-9328 ' 9380 ' -9419', 9427 ' -9511 ' Tubing (size, grade and measured depth) 4-1/2", L-80 tbg w/tail ~ 11909' Packers and SSSV (type and measured depth) WD pkrs @ 11302' & 11882', & SSSV ~ 390' , 11482'-11540', 11552'-11654' , 11660'-11774', 11920'-11975' , 9338'-9417', , 9631'-9674' RECEIVED 12, Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure A!~ska 0il & Gas Cons. Commission Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Inj, ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report :of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~-~ ~ ~./'.~-¢~_ Form 10-404 Rev. 12-1-85 ~/ ,/ Title Associate Engineer (Dani) SW03/49 Date Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should he summarized on the form giving inclusive dates only, District l.Stat~K ARCO Alaska, Inc. Field HEMLOCK, ' C' Auth. or W.O. no. AD6064 ICounty, parish or borough TRADING BAY UNIT Lease or Unit Title ADL: WORKOVER K-17 IWell no. API: 50-133-20248 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 01/09/88 ( TD: 12120 PB: 12010 SUPV: MAL 01/10/88 ( TD: 12120 PB: 12010 SUPV: MAL 01/11/88 ( TD: 12120 PB: 12010 SUPV: MAL 01/12/88 ( TD: 12120 PB: 12010 SUPV: MAL 01/13/88 ( TD: 12120 PB: 12010 SUPV:MAL IOate Complete record for each day reported ARCO 58 01/08/88 JHour 1100 ARCO W.I. 18. oooo Prior status if a W.O~ PREPARE TO TEST BOPE MW: 0.0 FIW ACCEPTED RIG @ 1100 HRS, 1/8/88. SET BPV. REMOVED WALKWAY/GRATING AROUND WELLHEAD. ND TREE. NU BOPE & PREPARED TO TEST. DAILY:S24,300 CUM:$24,300 ETD:S24,300 EFC:$732,000 FIW PREPARE .TO LAND HANGER MW: 8.5 TESTED BOPE. PREPARING TO LAND TUBING HANGER. DAILY:S12,150 CUM:$36,450 ETD:S36,450 EFC:$732,000 MW: 8.5 FIW POH, LD'TUBING BACKED OUT LOCKDOWN SCREWS. PULLED HANGER LOOSE @ 162K. FILLED HOLE WITH 56 BBLS FILTERED INLET WATER. PUMPED REMAINDER OF PILL OUT OF TUBING STRING. LD TBG HANGER, 2 JTS OF TUBING. MU BOP TEST PLUG AND LANDED SAME. RETESTED BOPE TO 3000 PSI. LD LANDING JTS, TEST PLUG & TIW VALVE. FILLED HOLE. POH LD TUBING (WET STRING). DAILY:S15,347 CUM:$51,797 ETD:S51,797 EFC:$732,000 RIH, PICKING UP DP MW: 8.5 FIW LD 4-1/2" TUBING (WET STRING). CHANGED TO 5" PIPE RAMS & TESTED TO 3000 PSI. PU FISHING ASSY. REPAIRED TORQUE GAUGE. PU DC'S AND DP. RIH. DAILY:S16,702 CUM:$68,499 ETD:S68,499 EFC:$732,000 WASHING DOWN TO PKR MW: 8.5 FIW PICKED UP DP. RIH. MIXED AND PUMPED 40 BBLS HEC PILL. SQUEEZED 20 BBLS AWAY. DAILY:S12,400 CUM:$80,899 · DAILY:S13,092 COM=$93,99~ ETD:S80,899 EFC:$732,000 RECEIVED' 01/15/88 ( TD: 12120 PB: 12010 SUPV:HMP MW: 8.~ FI. ~j~,:~:? 0 ~' !gS8 CHANGED BHA. RI~. SPEARED ~I~ska Oil & Gas Co~. ~~ .~ch0mge ~ ETD= $93,991 EFC= $732,000 POOH MW= 8.5 FIW CIRC. BOTTOMS UP. POH. DID NOT RECOVER FISH. REDRESSED -SPEAR & RIH. SPEAR FISH @ 11357'. PUSHED PKR TO 11406'. CIRC. BOTTOMS UP. SPEARED & BEAT ON FISH. POH. DAILY:S12,400 CUM:$106,391 ETD:S106,391 EFC:$732,000 The above is correct For form prepara, t. ion/~.nd~_di~!r_i_bu, ti~o., ~ATE ENGINEER ., ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describ ng work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ]County or Parish IState ARCO Alaska, Inc. TRADING BAY UNiT I A~( Field JLease or Unit HEMLOCK, ' C' I K-17 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 01/16/88 ( TD: 12120 PB: 12010 SUPV:HMP 01/17/88 ( TD: 12120 ?B: 12010 SUPV:HMP 01/18/88 ( TD: 12120 PB: 12010 SUPV:HMP 01/19/88 ( TD:12120 PB:12010 SUPV:HMP 01/20/88 ( TD:12120 PB:12010 SUPV:HMP 01/21/88 ( TD:12120 PB:12010 SUPV:ML 01/22/88 ( TD:12120 PB:12010 SUPV:ML 8) 9) 3) L) 1.~) li) I ) · ARCO ~58 RIH W/TAPER TAP MW: 8.5 FIW FINISHED POH. NO FISH. REDRESSED SPEAR & RIH. SPEARED FISH, POH; NO FISH. MU TAPER TAP & RIH. DAILY:S12,400 CUM:$118,791 ETD:S118,791 EFC:$732,000 CIRC. BOTTOMS UP MW: 8.5 FIW FINISHED RIH WITH TAPER TAP. CIRC. BOTTOMS UP. TAGGED FISH @ 11767'. ATTEMPTED TO WORK TAPER TAP INTO FISH. POH. LD FISH. MU MILL. RIH. TAGGED PACKER @ 11796' & MILLED OVER. WORKED PACKER. CIRC. BOTTOMS UP. DAILY:S12,400 CUM:$131,191 ETD:S132,441 EFC:$730,750 RIH W/BIT & SCRAPER MW: 8.5 FIW POH WITH MILL OVER SHOE. RIH WITH SPEAR. POH WITH FISH. RIH WITH BIT & SCRAPER. DAILY:S15,761 CUM:$146,952 ETD:S146,952 EFC:$732,000 RIH W/ RTTS MW: 8.5 FIW RIH. CIRC AND SWEEP HOLE W/ 60 BBLS HI VIS SWEEP. POOH. RIH W/ RTTS. DAILY:S43,517 CUM:$190,469 ETD:S190,469 EFC:$732,000 CIRC HI VIS SWEEP MW: 8.5 FIW SET RTTS AT 11375' AND TEST CSG TO 2500-PSI. CIRC BTMS UP. POOH. RUN CET/GR /CCL F/ 11940' TO 9500'. POOH AND RD SOS. RIH W/ BIT TO 12005'. NO FILL. DRLD FC AND CEMENT F/ 12005' TO 12025'. CIRC AND PREP TO PUMP HI VIS SWEEP. DAILY:S59,343 CUM:$249,812 ETD:S249,812 EFC:$732,000 RIH W/ PERF ASSY MW: 8.5 FIW CIRC HI VIS PILL. TOH. TEST BOPE TO 3000 PSI. PU SOS PERF ASSY. RIH W/ 5" DRILL PIPE. DAILY:S12,461 CUM:$262,273 ETD:S262,273 EFC:$732,000 . . CHANGING OUT FIRING HEAD MW: 8.5 FIW TIH W/ PERF ASSEMBLY. RU SOS. TIE IN W/ CET OF 1/19/88. SET PKR AT 11386' MD. POOH. RD SOS. ATTEMPT TO FIRE GUNS.. . REVERSE OUT DP. POOH. GUNS DID NOT FIRE. CUT DRLG LINE. CHANGE OUT FIRING HEAD AND TIV. DAILY:S12,400 .CUM:$274,673 ETD:S274,673 EFC:$732,000 no. The above is correct Signature J Date For form preparation and d~tribution see Procedures Manual S~'cj[ion 10, Drilling, Pages 86 and 87%/ ,'~ -7 !TM ASSOCIATE ENGINEER * ARCO Oil and Gas Company Daily Well History--Interim Instructione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative 'test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I' TRADING BAY UNIT Field JLease or Unit HEMLOCK, ' C' I K-17 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. ARCO 58 15) ARCO Alaska, Inc. ]Stat~ IWell no. 01/23/88 ( TD:12120 PB:12010 SUPV:ML 01/24/88 ( TD:12120 PB:12010 SUPV:ML 01/25/88 ( TD:12120 PB:12010 SUPV:ML 01/26/88 ( TD:12120 PB:12010 SUPV:ML RIH TO CLEAN OUT TO PBTD MW: 8.5 FIW FINISH CHANGE OUT OF FIRING HEAD AND TIV. RIH WIH PERF ASSEMBLY. PERFORATE 9-5/8" CASING 11600'-11650', 11660'-11710', 11730'-11770', 11920'-11975' WITH 5" 4SPF GUNS. REVS OUT DP. POOH. LD GUNS. PU BIT AND SCRAPPER. DAILY:S38,126 CUM:$312,799 ETD:S312,799 EFC:$732,000 TIE IN TO SET PRK ASSEMBL MW: 8.5 FIW RIH TO 12025'. DISPLACE HOLE TO CLEAN FIW. POOH. RU WL. MAKE GR/JB RUN TO 11900'. POOH. MU BOTTOM 9-5/8" PACKER ASSEMBLY. RIH. TIE IN WITH CET OF 1/19. DAILY:S19,588 CUM:$332,387 ETD:S332,387 EFC:$732,000 RUNNING 4-1/2" TUBING MW: 8.5 FIW SET BOTTOME PACKER @ 11882'. POOH. RIH WITH UPPER PACKER ASSEMBLY. SET 'WO' PACKER @ 11286'. POOH. RUNNING 4 1/2" AB MOD COMPLETION ASSEMBLY. DAILY:S345,851 CUM:$678,238 ETD:S678,238 EFC:$732,000 NU AND TEST TREE MW: 8.5 FIW RUN 356 JTS 4-1/2" 12.6~ L-80 AB MOD BTC IPC TBG TAIL @ 11345'. SSSV @ 390', PKR @ 11302' & 11882'. TEST TUBING TO 2500 PSI. CLOSE SSSV. SET BPV. ND BOPS. NU TREE. DAILY:S82,027 CUM:$760,265 ETD:S760,265 EFC:$732,000 The above is correct Signature i Date For form preparation and distr/i~ution see Procedures Manual Secti~r}f 10, Drilling,. Pages 86 and 87 ~CIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovera when an official test is not required upon completion, report completion and representative test clata in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Field HEMLOCK, ' C' Auth. or W.O. no. AD6064 Accounting cost center code State ICounty or Parish TRADING BAY UNIT Lease or Unit Ti'tie ADL: K- 17 WORKOVER API: 50-133-20248 IWell no, Operator kECO I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W,O, I 1100 Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 01/27/88 ( 1 TD:12120 PB:12025 SUPV:ML IA.R.Co. W.I. 18.0000 Date 01/08/88 Complete record for each day reported ARCO 58 RIG RELEASED MW: 8.5 FIW TEST TREE TO 5000 PSI. RELEASE RIG @ 1200 HRS 1/26/88. DAILY:S7,990 CUM:$768,165 ETD:S768,165 EFC:$732,000 Old TD Released rig Classifications (oil, gas, etc.) I~m~clng math'od Potential test data JNew TD I PB Depth Date IKind of rig Type completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing interval Oil or gas Test time Production · Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date ' corrected I _. The above is correct Signature see Procedures Manuat,(~ection 10, Drilling, Pages 86 and 8~. JDate ITitle ~.~ -~ H- ,'~ A880CIATE ENGINEER STATE Of ALASKA ALA ..... ,A OIL AND GAS CONSERVATION COk...~ISSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate,~ Other 2. Name of operator UNOCAL (ARCO Alaska, Inc. is sub-operatorI 3. Address P. 0. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg 1, Conductor 4 694' FSL, 83' FEL, $ec.17, TgN, R13W, SM At top of productive interval 1609' FSL, 1073' FEL, Sec.21, TgN, R13W, SM At effective depth 1~73' FSL, 929' FEL, $ec.21, T9N, R13W, SM At total depth 1209' FSL, 905' FEL, Sec.21, TgN, R13W, SM 5. Datum elevation (DF or KB) RKB 100' 6. Unit Or Property name Trading Bay Unit 7. Well number K-17 (44-21) 8. Permit number 73 -01 9. APl number 50-- 133-20248 10. Pool Hemlock & "G" Pool feet 11. Present well condition summary Total depth: measured I 2120 'MD feet true vertical 9782'TVD feet Plugs (measured) None Effective depth: measured 1 201 0 ' ND true vertical 9696'TVD Casing Length Size Conductor 352 ' 24" Surface 21 53 ' 1 3- 3/8" Producti on 1 2066 ' 9-5/8" feet feet Junk (measured) None Cemented Measured depth Pile Driven 382 'MD 13-71 Sx Class G 21 83 'MD True Vertical depth Perforation depth: measured 11420'-11460', 11482'-11540', 11552'-11654', 11662'-11774' true vertical 9233'-9264' 9283'-9328' 9338'-9417' 9424'-9511' 800 sx Class G 12096'MD Tubing (size, grade and measured depth) 4-1/2" 12 6# N-80 .BTC ~ 11332' Packers and SSSV (type and measured depth) 2 Model D's ~ 11795' & 11300'- TRDP-1A 12.Attachments 382'TVD 2031'TVD 9764'TVD Description summary of proPosal J~ Detailed operations program [] BOP sketch ~. 13. Estimated date for commencing operation November 16, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certj,fy that the fore og~_z~g is true an,d/correct to the best of my knowledge .. .~ .~L~"~-~'~.. ~~'~-~' T"le ~igneo Candace [ockw~) ...... '~z,k " FnvirnnmPnfal qpec~a!ist Conditions of approval Approved C~.~ Returnee ...... Form 10-403 Rev 12-'I-85 Date 11/1 Commission Use Only (TJB) SA3/14 .Notify commission so representative may witness [ Approval No. [] Plug integrity [] BOP Test [] Location clearanceI '/ ""'~ L by order of the commission Date ~l//~'/~ Submit in triplicate ~_~ KING SALMON PLATFO~'' WORKOVER PROGNOSIS WELL TBU K-17 OBJECTIVE Replace scaled-up tubing and gas lift mandrels, re-perforate production zones, and perforate new production zone. PROCEDURE , . Move rig over well TBU K-17, leg #1, slot #4. Kill well with NaCl brine (expect 3800 psia bottom hole pressure @ 9450' TVD). 3. ND tree. NU and test BOPE. 4. Pull and lay down 4-1/2" tubing string. . Mill over and recover two Baker Model "D" permanent packers set at 11300' MD and 11795' MD inside 9-5/8" casing. . Pressure test the integrity of squeezed perforations in Hemlock Bench 5, and re-squeeze if necessary. , Pressure test 9-5/8" casing, and cement squeeze any casing leaks found above the perforated interval. 8. Clean out any corrective squeezing as directed. Clean out to PBTD @ 12010' MD. 9. Run casing inspection log from PBTD to surface. 10. Perforate Hemlock Benches 3, 4, and 6 under 500-1000 psi drawdown with 5" drill pipe conveyed guns (approximately 150' of guns with 4 SPF and 150' of blanks will be required). Drawdown may be achieved with a partial fluid column in the drill pipe. 11. Run new 4-1/2" tubing completion assembly (see attached completion diagram). 12. ND BOPE. NU tree. RD and prepare rig for next well. · Workover fluid: Filtered inlet water w/3% KC1 or NaC1 K-17 PROPOSED COMPLETION 110#, X52 O 382' SSSV, 3.813' ID, 380'± ~ 13-3~", 61#, K-55, BTC @ 21~' 4-1/2', 12.6#, N-80, BTC I 2545' 2 41 52' 3 5461' 4 6457' 5 721 6' 6 7723' 7 8221' 8 8717' 9 9206' 1 0 9692' 1 1 1 01 93' 1 2 1 071 3' 1 3 11 247' Ii imm mm ~im m ImI mmI mm 1,2,3, 4,&6 TD @ 12120' 1/26/73 mm mm ,mm mm mm mm mm mm m mm mm PERMANENT PACKER @ 11330' 3.75" ID NIPPLE @ 11352' TUBING TAIL W/RE-ENTRY, 3.875" ID @ 11363' PERR~ATED INTERV~'APPRO~ 11420'- 1 2040' PBTD @ 12010' 9-5/8", 43.5#, 40#, RS-95 BTC @ 12096' 13-5/8" 3000 PSI BOP STACK ANNULAR PREVENTER 6 II ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BLIND RAMS 4 1. FMC TYPE III UNIHEAD 2.13-5/8" 5000 PSI HUB X 3000 PSI FLANGE ADAPTER 3.13-5/8" - 3000 PSI DRILLING SPOOL 4.13-5/8" - 3000 PSI BLIND RAMS 5.13-5/8" - 3000 PSI PIPE RAMS 6.13-5/8" - 3000 PSI ANNULAR 10. 11. 12. 13. 14. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD, 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5i INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUI~S. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNS'I'REAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO .PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 9, 1987 (FOR TBU WELLS) MEMORANDUM TO: TH RU: FROM: · State, of Alaska .~- ALASKA OIL ~AND GAS CONSERVATION COMMI '~ON Cc~~terton DATE: March 17, 1986 Lonnie C. Smi -Commissioner Edgar W. Sippl~- Petroleum Inspector FI LE NO.: D. EWS. 3 TELEPHONE 'NO.: SUBJECT: No Flow Test ARCO TBU #K-17 McArthur River Oil Pool Thursday, March 13, 1986: I traveled this date from Anchorage to Kenai'~via ERAto Witness a No Flow Test on ARCO's King Salmon Platform Well NO. K-17. The water cut on this well is 83%. The gas lift was shut off from this well at 12:00 p.m. Wednesday. The well was flowed into the SWAB Separator until it stopped flowing. The total amount of liquids from this well during the test was 99 bbls. The well was then diverted into the Production Separator which was opened into the skimmer tank which had 3 oz. of back pressure. When I checked the well at 10:00 a.m. Thursday, there was a small amount of gas flowing into the Production Separator. The operator opened the needle valve on top of the tree. There was a small amount of gas, with no liquid coming from the well. To make sure there was no buildup of the gas, the operator installed a manifold with a 0-2000 pound calibrated gauge with 10 pound increment marking. The well was shut in for 1 hour and 30 minutes. There was only 5 psi buildup. The manifold was opened up to atmosphere with no-liquid return and only a small amount of gas. Attached to this report is the flow chart from the SWAB Separator and Production Separator. In summary, I witnessed the No Flow test on ARCO's King Salmon #K-17 well, and verified that it is incapable of unassisted flow. o~ AM~ \ ,, STATE OF ALASKA ALASKA~-~L AND GAS CONSERVATION C(~:MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OX 2. Name of Operator 7. Permit No. Union 0il Company of California 73-01 3. Address 8. APl Number 909 West 9th Avenue, Anchorage, AK 99501 50- 133-20248 OTHER [] 4. Location of Well Surface: King Salmon Platform K-17 Leg #1, ConductOr 4 5. Elevation in feet (indicate KB, DF, etc.) 12. 100' MWL 6. Lease Designation and Serial No. ADL 17594 9. Unit or Lease Name Trading Bay Unit 10. Well Number K-17 11. Field and Pool McArthur River - Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repai-r Well ~ Change Plans [] Repairs Made [] Other [] Pull Tubing . [] Other [] Pulling Tubing [] (Note; Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., as sub-operator, proposes the following repair of K-17: _ a) Rig up over leg #1, conductor #4. b) Kill the well with filtered Inlet water. c) Pull completion assembly. d) Cleanout fill to PBTD (12,010'). e) Recomplete with 3-1/2" tubing. f) Reperforate selected intervals of the Hemlock w/4 spf under drawdown conditions. A 13-5/8" SRRA BOP stack will be used on well work. each trip. A 3000.psi WP wireline lubricator will be used and tested on all wireline work. safety valve will be installed & tested upon conclusion of the job. Estimated Start: November 15, 1983 ~ E [E ~ V E The BOPE will be tested weekly and operationally tested A new subsurface Gas C0ns~ G0mmissi0n Anchorage 14. I hL~~e rtify th:t the,;r~ego~ ~_ig e below for Commission use itle ~i~ions of APproval, if any: Date true and correct to the best of my knowledge. Di st. Dri 11 ing Superintendent BY RA~RY W. K[JGLEii ~..~ Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Date__ Form 10-403 Rev. 7-1-80 GRUS/SN05 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1o10-73 Subml t "1 ntentlons" In Triplicate ,*subsequent Reports" in Duplicate STATE Or ~LASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS {Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.} 1. OIL B GAS B WELL WELL OTHER NAME OF OPERATOR Union Oil Co. of California* ADDRESS OF OPERATOR 909 W. Ninth Ave., .Anc,hOrage, AK 99502 ' APl NUMERICAL CODE //~ - 50-133-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN, ALLOTTEE OR TRIBE NANtE 8. UNIT. FARIV[ OR LEASE NAME Trading ..Ba.y Unit . ~.~"~" 9. WELL NO. '. . ~ _ K-i7 (43-21) 10'. FIELD AN D' 15DEL',' O R 'WILDCAT/' . LOCATION OF WELL At su~ace 694' N & 83" W o'f SE Corner SEc 17,.T9N, R13W, SM 33. ELEVATIONS (Show whether DF, RT, GR, et~) K.B. 100' above ML·LW McArthur River - Hemloc'k 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 21, T9N, R13W, 'SM 12. PERMIT NO. 14. Check Appropriate Box To Indicate Nature of Notice, Re : · NOTICE OF INTENTION TO: .. PULL OR ALTER CASING MULTIPLE COMPLETE . ABANDON* CHANGE PLANS TEST WATER SHUT-OFF FRACTU R E T R EAT SHOOT OR ACIDIZE REPA'I R WELL (Other} 3oft, or Other Data SUBSEQUENT REPORT OF= I----1 WATER SHUT-OFF- L--J REPAIRING WELL FRACTURE TREATMENT ' H AL'fERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Reperforate existing interval~ (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 35. DESCRIBE PROPOSED OR COMPLETED'OPERATIONS (Clearly state ali-pertinent details, and give pertinent dates, Including estimated ~[ate of starting any proposed work. . 'The following Hemlock 'intervals were reperforated on September 29 and 30, and October 1: _. 11423-11439 DIL 114-43'11458 DIL 11602-1165-4 DIL. 11662-11704 DIL 11731-11773 DIL *ARCO Oil .&. Gas ~ompany, Suboperator SIGNED ...... DATE. 11/06/80 TITLE-District Engineer (Thls space for State office use) APPROVED BY CONDITIONS OF APPROVAL. IF ANY: TITLE - ' DATE Instructions On Reverse Side · Form 10-403 REV. 1~'10-73 Submlt"lntentions" 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 {o deepen Use "APPLICATION FOR PERMIT--" for such proposals.} 5. APl NUMERICAL CODE 50-133-2024.8 6. LEASE DESIGNATION ANDSERIAL NO. ADL 17594 WELLI~J WELL OTHER 2. NAME OF OPERATOR 8. UNIT. FARM OR LEASE NAME Union Oil Co. of California* Trading Bay Unit ADDRESS OF OPERATOR 909 W. Ninth Ave; Anchorage, AK 99502 · 4. LOCATION OF WELL At ~ace 694' N & 83' W of SE Corner Sec 17,.T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, et~) K.B. 100' above MLLW Check Appropriate Box To Indicate Nature of Notice, Re : . NOTICE OF INTENTION TO: .-. FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ~ ABANDON* REPAIR WELL ' L_._J CHANGE PLANS (Other) Reperf Existing Intervals 9. WELL NO. K-17 (43-21) 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 21, T9N, R13W, 'SM 12. PERMIT NO. ~ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ,,, ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recom01etion Report and Log form.} 15. DESCRIBE PROPOSED OR COMPLETED'OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. _We propose to reperforate the following intervals: _ - 11571 - 11602 DILl/ 11602 - 11654 DIL 11662 - 11704 DIL 11731 - 11773 DIL Subsequent Work Repol~ed '" - *'ARCO Oil and Gas Company, Suboperato~. 16. I hereby certify that the foregoing is true and correct S,GNED T,TLE C.' H, case (This space for State offi~. ) .-i CONDITIONS OF APPROVAL, IF ~(IY: BY ORDER OF. TH~ COt~glSSION District Engineer DATE 9/16/80 COMM!SSZONER DATE ~ Atlantic,r',ic:.fic!dCc::?~ny Sou~q Alaskn District i RA ~' - ,, S P, i T T A L (0 f f i ce.J From-~-'o,~._~ ~Z. o~d ~,,-Z -/7£Co_ _-._,,g,~/c ~-/ .. t, Of f i cc) -- ~' ubject wel 1 · :'ansmit~d herewith are the following for .~ne s . o. :", ~, n No. Scale Xerox Se.pla BI Line _ I .... :.,, B}[C Sonic/Caliper Log BHC Sonic/Call ~ ° ~ p:r-~d~ma Ray Log BHC Sonic-Gamma Ray [~cutron Cement Bond Log ~7c:oo$7"/~ .. Continuous DJpmeter (HRD) Continuous Dipmeter PollJwog Plot . Continuous Dipmet.er Printout Core Anaiysis Interval Core -Core description (S~ZC) tntervai Core description (Cony) Core Core's (~4et)(Bry) Interval Dircctiona] Log Dr. i]l Sicm Test : Test "~,o'. Dual induction Laterolog FD FS Formation Density Lbg H [ c r'o ]og 14udlog lnte~ va~ Proximity-H[cro]og/Calipe~ Leg Sample Log (ARCO) Interval 'Sidewall ~:eutron PoFos[ty Samples (St.[C) Interval No. Boxes Samples (Conv,)Core 1~o. No, Doxes - Z ~.t ~ z'o_i, oz R~.t'urn recei?t to- Atlantic Richfield District Geologist P. O. Box 360 Anti,oracle, Alaska 9750i DIVISION L.t,: OIL AND GA5 ANCHORA~ AtlanticRichfieldCompany North Ame~an Producing Division North Ala,~ District Post Office 8ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 2, 1973 State of Alaska Department of Natural Resources 0il & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. Homer Burrell Re: Trading Bay Unit Well K-17 (43-21) Sec 17, TgN, R13W, SM Permit No. 73-01 Gent lemen: Enclosed is the original and one copy of the Notice of Well Completion with attached well history for the Trading Bay Unit K-17 (43-21) well. Electric logs will be submitted under separate cover. Please acknowledge receipt of this material by returning one signed copy of this letter for our files. Veryo triply yours, B. T. Loudermilk Dist. Drilling Supervisor BTL/JWS/ll Enclosures RECEIPT ACKNOWLEDGED: '£t)TAL DfitYrH. MD & TVD~9. PLUG. BACK I%lD & TVDp. (t,~)) 9796'TVD [12010.'MD 9710' (TVD)] aow~,.¥. ] 0-12120~°~^~x' TOOLs PRODUCING [NTERVAL(S.~. OF 2qq.]S CO51PLETIO~--TOP, BOI'FOM, NAME ;MD AND T1;I))- 11423' (MD) 9250' (TVD) Hemlock 11771'~ (MD) 9523' (TVD) Hemlock STATE ~s~ ,~i-,r OIL AND GAS CON~ATION CO~Dr~~ '~'" ......... '~'! '~~ -_ ...... ~ ....~ ~ MAY ~. ~7'~ , .. I 50-Z33-20248 WELL COMPLETION OR RECO~~DN ~O~~G* IR ~0 T AND LOG* WFI.I (~VE/ ~ [N ~ BACK r. ESVR. Other Union Oil Comply of California 9. W~L~O. ,~ o~ o~,~,~o~ K-17 (43-21) LOC~TION OF WELL ~Report location cl*'a)'/~ and in accordance tcitK a~p ~'tate requirfment~l* Hemlock A~ surface 11. SEC., T. R,, 694'N & 8~'%~~ fr SE cr of Sec 17, TgN, ~3W, SM A~ ~op prod Interval reported below 1719'N & 874'W fr SE cr of See 21, TgN, ~3W, SM Sec. 21~ ~N, ~3~, SM At total dep~ 13~'~ & ~7'W fr SE e~ of See 21, Tgi, ~3W~ SM 73-0~ INTER%'ALS DRILl,ED [~Y (:^ si, g TOOLS 23. WAS DIRECTIONAl, SUil V~'Y A'IADE Yes 24. TYPE EL??.C'VRIC £,~ND OT.i{IKi% LOGS RUN DIL, GR Sonic, FDC an& ~L CASING RECOED iEuport ail strings set tn w(ll) ~T:~'~ ~~ 1~-55 I 2z8~' [~/2" ¢s7'~ 26 LINLX E.ECO~ ] 27. ' TUBING 2/i. PERFORA'i'IO.%S OPEN TO PRODUCTION (intcrval. size and number) Perforated w/four 11,423-11,443 ' 0.36" JSPF 11~ 482-11,532' 11,552-11,637~ 11,663-11, 723 ' 11: 736-11,771' 30. PR. OD UCTiON [ [2.!-t{OUR RATE i 150{ 1095 { ~~ { 4972 BPD I 1150 MCFD and tr~smStted to shore DA'i'I:; FiIiSI' PiiODU~TiON--~ PRODUCTION MElt'tOD ,.Piov.-ii-g. ~.:.~s llfi, p~mping--size and type of 3-18-73 } .__ Gas Lift O 1L,---t3DL ~ AS----M CF. ~.-~ell HisLory, Directional Survey { V I;LI., ~'FA'I US i t-'i'od,:clng or ProducinK. 1022 I 10j 231 %%'AI~R--LlBL O{L G!~:kVI'I'Y-A.Pi (CORI~. } ] 20 ~P~~ %.6 [ 'I'E~'i ,v IT ESN~ ...... t Dick Smith ~~"~f.,,' t.h. at the tt, regutng and attached lrff,,rmati.n Is complete' and'correct as ~~~~;::sflW ,,-- ~ ~_. tiff n ---n, Dist. Drlg. Supt. ~,,_ ._ ~~_,.~~ .,-,- ................... ~ *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed, for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item: 16,: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form a'nd ~r'~ any attachrr~er~ts. Items 20, ~,ncl 22:: If this well is completed for separate production from more than one interval zone (multiple comptetion)~ so state in item 20, and in item 22 show the prcJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval ret)erred in ite'm 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce,"l, show- ing the ackJitional data pertinent to such interval. Item2&: ",S~cks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing to01. Item 28: Submit a separate completion report on this form for each interval to be separately producad. (See instruction for items 20 and 22 above). , , "A" ~,rker 3572 ' 3077' "B" Marker 4267' 3594' "C" ~rker 5120 ' 42h2' None "D" ~rker 5606' 4624' "E" M~ker 8028' 6557' · "F" Marker 9004' 7348' "G" Marker 10440 ' ~ ...... 8550 ' 9248' He~ock 11420 ' , , · ' . .. · West ore as 2060' D~c~tPmoNs OW:L~T~tO~G%'. PO~O~. F*tA~R~. ~PP~ D~PS . · ,, ~Fted', ~ D. ily work prior to opuddinf ,hould : DAILY ~ELL RI/sToRY-!NIT-IAL REPORTMAY 4.-1973 ,-- DIV~Sh;t-~ Cf: OIL-AND GAS District SO~H .A~s-KA ,..: ..... ~unty O~'Paris~,::KenaiL ,; ,:AS~CHO~-e ,, ,ALAS~ Auth. or W.O. No..199176 . ,' .... .Ti-tle-Dril'l ~Devet°Pment"Oil,Wel! Operator .ATLANTIC RICHFIELD 'COMPANY .............. TARCO~S W.I. ]2'9% Spudded or 'IPrior. Status W.O. Begun,SPud 'Date 1.:26-73 ,, , Hour 6:00,.AM if a W. O. . Date & Depth as of 8:00 A.M. 1-25-73 1-26.-73 1-29-73 1 30-73 1-31-73 2-1-73 2-2-73 Complete Record for each Day Reported , K-17 (43-~1) - COOK INLET General RU. Working on rotary clu%ch. Installed new mud guns.' Set mouse hole & rat hole. Mixed 800 bbls mud. Working on rig.heaters. K-17 (43-21) - COOK INLET General RU, rig repair, .mix mud, Prep to spud @ 6:.00 AM. TBU K-17 (43-21) - COOK INLET 2247' (2247') - Opening hole to 17-1'/2" - MW?9',l#,Vis 44. Spud 6:00 AM 1-26-73. Drilled 17-1/2" hole to 600' Dri!led directional 12-1/'~" hole' to"2247". Opened hole to 17-1/2" 600-i400'.' Survey: 2205' TYD2030 S69E S131 E686. TBU K-17 (43-21) - COOK IN'lET 2247' (O') - Running 13-3/8" csg - MW 9.2#, Vis 46. . Opened hole to 17-I/2" to 2246', circulated 3/4 hr, made wiper trip, circ -2-3/4 hrs, MOH OK. RU & began running 13-38" csg. TBU K-17 (43-21) - COOK INLET (13-3/8" @2183') 22~7' (O') - NU BOP stack - MW 9.2#, Vis 47. Ran 54 jts 13-3/8" 61# K-55 butt csg, set @ 2183'. Cemented with 811 sx Class G cmt w/lO% gel & 2% CaC12 plus 560 sx Class G cmt. Full returns, cement circulated. CIP 4:15 PM 1-30-73. ND riser & 20" Hydril. Installed Unihead valves. NU BOP stack. TBU'K-17 (43-21) COOK INLET - (13-3/8" ~ 2183') .2247' (O") - Tstg BOPE. Installed 13-5/8" BOPE Stack w/blinds on top. Connected choke manifold. Installed flow nipple., Reset flowline. Tested choke manifold w/5000 psi. Top valve leaked. Redressed valve. Set test plug. Attempted to test pipe rams. Leaks in lines to manifold & test plug rubbers now damaged and leaking~ TBU K-17 (43-21) COOK INLET - (13-3/8" @ 2183)) 2247' (O') - Trip in to drill out - MW 9#, Vis 40, WL 14.6. Tested manifold valve w/5000 psi OK, blind rams w/5000 psi OK & Hydril w/3OO0 psi OK. Repaired mudline union leak. Ran in to drill out. . , Distribution: Orig.: Drilling Section- Dallas cc:- District Office Eng~ineering Division - '(720) Co-Owner(s) - As Appropriate Regional Office, :Well Record File PAGE The Above is Correct: ' / .." I r.; -- · , .-"' .'" .?,',', .,'_~ - $'i'GI~.' A:TURE-- ' DATE :. DistriCt Drilling..~Ul~rintendent- T I TL E: (NUM~BEH ALL DAILY WELL HISTORY FORMS coNSEcuTIVELY AS THEY ARE PBEPAft£D FOB EACH WELL. , . , . : : . ., · . ~-~ . : ;:, . , . _ (' --)'i 3.B-459~1 '-' · '"' - - :-: ': - '------ '--'-.¢-.- - - - MAY 4 1973 ' ': '~'~ ..... "' ' --D~ILY WELL,-'H~'STORY -. INTERIM · F~eld T~DING BAY UN!~' ;.,, ~.se oF ~n~ K-17 ,, .. Complete Becord.for each Day While Drillin~ Date & Depth at 8:00 A.M.- 2-5-73 · 3838' 2-6'73' 4057' -. '2--7-73 4~22' o 2-8-73 5140' _. 2-9-73 57871 2-12-73 7080' 2-13-73 7560' 2,14'73 7890' TBU K-17 (43-2i) - COOK INLET- (13-3/8" ~ 2183') 3838' (1591') - Trip in w/turbo #3 - MW 9.2#, Vis 40,' WL 10.5. Tested 13-3/8'" csg w/1500 psi OK. Drilled-out cement & float equipment. Cleaned out to 2247.",.drilled new hole ~o 2257'. Tested.shoe w/equivalent 0.55 psi/foot pressure gradient. .POH. Ran gyro survey 2180' to surface. Drilled to 2765'. Ran. Turbodrill #2 2765-2957'. Drilled 2957-3838'. POH for.turbOdrill #3. Survey:. 3766' TVD3237 43° S62E. . TBU' K-17 (43-21) - COOK INLET (13-3/8"-~ 21.83') - 4097' (259.') - Prep to POH to Change assembly '- MW 9.2#, Vis 44, WL 10.5' -Ran turbodrill #3 3838-4021', .POH' E~ectric drawworks brake failed. RIH s.low.ly,"drilled'.ahead-.to.4097'. -- Survey:'- 4057'.~TVD 3452 4i° S.49E- __ . . TBU K-17 (43-2i).- COOK INLET (13-3/~' @ 2183') 4922.'-(825') - Drilling - MW. 9.1#, Vis 40,"WL ]O.8~ Drilled 12-1/4" hole 4097-4~2Z'. Drilling.. .. · "'TBU K-17 (43'21) - COOK INLET. (13-3/8" ~ 21'8.~')" 5140' (218') - Working on electric brake- MW 9.1#,' Vis 40, WL 1'0.8, Drilled 12-1/4" hole ~922-5140'. " SurveY: 5090'.39-1/4~ S48E~ - -"' - . TBU K-17' (43-21) - cooK INLET (13-3/8'' ~ 2183') 5787' (647') - Tripping'- MW 9.2#, Vis 40, WL 9.5. Drilled 12-1/4" hole 5140-5787'.. Survey: 5740' 38-1/4° S46E. TBU K-17 (43-21) - COOK INLET (13-3/8" @' 2183') 7080' (1293') - Drilling - MW 9.3#, Vis 44, W.L 7.4. . Tested BOP. Drilled' 12-1/4I' directional hole to 5940' stuck pipe, jarred free- Drilled to 7080.'. Survey: 6678' TVD5483 36-1/2" S42E. TBU K-17' (43-21) - COOK INLET (13-.3/8"'1~ 218~') 75601 (480').- Drilling- MW 9,4#, Vis 46, WE 7.5. Drilled 12-1/4"'directional hole 7080-7560'. Survey . 7123' TVD5836' 37-1/·2° S38E.. TBU K-17 (43-21) - cooK INLET (13-3/8" @ 2183') 7890' (330') -Drilling- MW. 9.4#, Vis 44, WL 7.2. Drilled 12-1/4'r directional hole 7560-7890'. Survey.: 7673' TVD6272' 37'1/2o S37E. . The Above is 'Co:rrec, t': S/GNA~ ~I,'~e NO. 2 : (~n ALL ~ZLY WELL DiStrict Drl ] ! inM Superintendent "'~H . : : ' ' - ' ". ' .... . ,. 3B'4S9-2 lJ/JJ ..~ ~'?~'%~ 'Fi~A~-fem-. (~)~'i~:-'l~~' ,he~, ,hen f~l~d:, out bu~ ~t le,, frequ'em~ly t~ ,vem~ ~O..-d,y,. or (2)~- ed~eodsy Field' ~I~G ~Y ~IT _ ~ase or Unic K-17L"r '. ~'~LW~N~ 43i[ , - . ~ · , - , ~ ,, ,,, ,, ,, , ,, .. . ' Date & Depth at 8:00 A.M.' 2'15-73 '- 8179' Complete Record .for each Day While Drilling' or Workover in Progress K-17 (43-m) - COOK INLET (13-3/8" 2183' ) 2,16-73 8346' 2-20'73 ' 9532' 2-21-T3 9556' 2-22-73 . .9761' TBU K-iT. (43-~I) - COOK INLET (13-3/8"-@ 2183') )50-133-20248) 8346' (167") - Drilling.- MW 9.4#, Vis 43, WL 7.2. Drilled 12-1/4" directional hole to 8246' trip for bit, Test BOPE WIH. Drilled .to 8346'. -. ' TBU K-17 (.43,21).- COOK'~- 50-133-202'48 <13-3/8" ~ 2183") 9532' (1186') - Drilling - MW'9..4#,. Vis 48, '~L 6.'8'. -. " Drilled 12'1/4"-directional hole _8346-9532'. .: -' .- . -- TBU K-17 ('43-21') - COOK INLET -' 50-133-20248 (i3-3/8" ~ 2183') 9556" (24') -Going in hole ' MW 9.4#,. Vis .48, WL.6.8. Drilled to 9556"; on trip out stuck pipe @' 4327', worked 'Pipe to 320000#, unable to .pull free. cirn OK. RU surface jars, Jarred down on pipe, came free. Rotated out '5. Singles and POH. -. ,. TBU K-17 (43'21) -COOK INLET..- 50-133720248 (13-3/8" ~ 2183') 9761' (205') - Drilling-, prep-to POH,-MW 9.5#, Vis 47, WL'6.4.- RIH OK & drilled 12-1/4" directional hol~ 9556-9761'. 2-23-73 9815 ' 2-26-73 10407' 2-27-73 10560 ' 2-2'8-73 10776 ' TBU K-17 (43-21) -COOK' iNLET- 50-133-20248 (1'3-3/8"~ 2183') 9815' (54') - Drilling - MW 9'.5#, Vis 43, WL 6.'6. On trip out from 9761' worked thru tite. hole 5490-5270', finished out of hole OK. Tested BOPE, repaired wellhead. Trip in w/new bit OK. Survey: 9713' TVD7922 35-3/4° S32E. TBU K-17 (43-21) - COOK INLET - 50-133-20248 (13-3/8" ~ 2183') 10407' (592') - Drilling' MW 9.6#, Vis 42, WL 5.8. Drilled to 10017', made 20 stand short trip, pulled.tire to 9900'. Drilled to 10159',-trip for bit. POH. Pulled tite off btm. RIH, ream to btm from 10100', drilled ahead to 10335'; 20 std short trip ~. Drilled ahead. Survey: 10090' 36-1/4° S33E. TBU K-17 (43-21) - COOK INLET - 50~133-20248 (I3-3/8" ~ 2183') 10560' (i53') - Drilling -MW'9.5#' Vis 43, ~ 5.4. Drilled to 10552', trip.out, pulled 350000# up to 8100', tigh~450-5250', tite ~ 3000'~ WIH, reamed 30' to btm, mud off bottom gas cut to 9.1# for 120 bbls. Drilled ahead in 12-1/4" directional hole~ Survey: 10498' TVD8540 38-3/4° S36E. TBU K-17 (43-2i') - COOK INLET- 50-133020248 (13-3/8" ~ 2183' ) 10776' (2t6') -.Drilling - MW 9..6#, Vis '43, WL 5.6. Drilled to 10763', made 20 stand wiper trip OK. Drilled. ahead in 12-1/4" directional hole. The Above is Correct: SIGnATUrE'- -/ ..... ~ Di~tct ~illing Superintendent TIT~ ALL ~ILY UE~ HI.S~Y '~S ~SE~'I~LV AS ~ ~ ~ARED ~R ~ WELL. ) 4-17-7~ Field - ~I~ BAY ~IT ~ase or Unii.. 1-17 DIVISION ~.E OIL A ~ , - ., i ,, -,~ ~ r ~. 'r i ~' ,~ , · ' ~ ' Date ~ Depth Complete Record for each Day While' Drilling or Workover in Progress at 8:00 A.M. - _- ...... , ~ , 10981' 10981' (a0~") - ~illing-.N 9.6~, Vis hS, ~ 5..h. -_ ~illed 12-1/4" directional hole , 3-a-73 ~u K-lT. (23-~m) - COOK IN~T -' 50-133'~0~28 (13-3/8" ~ ~8~' ) 1!091' 11091' (110'), ~ Testi~ BOP - .N 9';6~, Vi~ ~5, ~ 5.~. ~illed to 11091', trip out. Mled ~ w6rked to 370000~ ~ 10980' , ~lg to 350000~ up .to. 8250', ~ag ~ 3275' ~ 2183' csg shoe. Test BOP, replaced , . ~il reg~ator. S~ey:' 110~' ~89~1 ~0-1/~° S3~E. -. ... c00 ' 0 S SOSh-S aSS' ) .. 11~30". -~430' (339') -'~ippi~.- ~ 9;6~', Vi~ ~8,-~'5.2. '- . ~ip in.-~ 11091'., ~illeg' 1~-1~". ~'reciion~ hole to: 11310' ,' 10 s:t~d ~per- trip 01. ~ill~d-.to E~", ~opped s~ey.';~tp out 0~. -- S~veF:' ~369' ~a08' ~0-1/~° S33E._ - . 3-6-73 ~U K-iT (~3-a) - COOK I~'.-=5'0-133'202h8 (13-3/8" ~ 2183') ~556' 11556' (126') - ~i~lin~-' ~ 9;6~, Vis ~2, ~ 5.6. ~ip in w/ne~ bit 0K, ~illed 12-1/~"' air'eettonal hole 11~30~1!556'. .. 3-7-73 ~U K-17 (~3-21) - COOK I~T ~ 50-133-202~8 (13-3/8" ~ ~83') .11736' 11736' (180') - ~ep ~o POH- ~ 9.6~,-Vis ~, ~ 5.~. ~i~ed' %o 11572', ~de 30 s~and ~per trip, 28 st~n~s 'p~le~ 360-370000~. ~illed to 11736', prep %o POH. : _ 3-~73 ~U K-l? (h3-21) - COOK I~T 50-133-202h8 (13-3/8" ~ 2183' ) ~8~3' 118~3' (107') -~illing- ~ 9.6~, Vis ~3, ~ 5.~. ~ip for new bit. Drilled 12-1/~" direction~ hole to 118~3'. S~ey: 11676' ~~9 3~1/~° S31E. . 3-9-73 ~U K-II (~21) - COOK I~ - 50-133-202~8 (13-3/8" ~ ~83' ) 12060' 1~60' (217') - ~illing - ~ 9.7~, Vis ~, ~ 5.8. ~ille~ to ~918', m~e 30 std wiper trip, 1st 28 stan~ rite. ~illed to 11989' made tire co~ection, worked pipe ~til free' Ran to bot%~ 0K drilled ~ead %o 120~7', made i0 std wiper %rip, ls% & ~d stands %ire, drilled ~ead %o 12060'. 3-12-73 ~U K-1?' (~3-21) - COOK IN~T- 50-133-202h8 (13-3/8" ~ ~83') 12120'TD 12120'TD-(60') -~ing 9-5/8" csg '-~ 9.8~, Vis ~5, ~ 5.8. ~illed %o 12069', .circ. ~de 35 stana wiper trip 0K. Cite to log 3 ~s. 0K. RU Se~, r~ DIL ~o 6000', ~ool failed. Ran bac~p DIL 1206h-alSh' , so~c 1206~-218h' FDC 12060-8900' ~H $ ~illed %o 12120' circ ~e 20 stand wiper %rip. Cite'for csK ~ ~S, POH. RU & s%~ed r~nin~ 9-~/8" cs~. S~ey:. 12012' ~711 3~1/2° S29E, . 3-13-73 ~U K-17 (~3-21) -COOK I~T- ~0-133-202h8 (13-3/8" ~ 2183') 12120'TD 12120'~.- Cite 9-~/8" cs~ on btm - ~ 9.9~, Vis ~3, ~ ~.6. Ran 306 ~%s 9-~/8" ~3.~ & ~0~ ~-9~ but% csK, lanaed ~ 12096'. Circ m~. The Above ~Correct: ~-17-73 DATE DistriCt Drilling Superin,tendent TxTLz NO' ~.~ ('NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ABE PREPARED FOR EACH WELL. ) r. 3B-459-2 12/67 Date & Depth at 8:00 A.M. .3,14_73' 12120 ' TD 3'i5-73 12120 ' TD 3-i6.-73 12120 ' TD 3-19-73 12120 ' TD 3-20-73 12120 ' TD 3-21-73 12120 'TD 3122-73 12120'TD TBU K-t7 (43-21) - COOK INLET' 50-133-20248 (9~5/8" ~ 12096') ' i2120"TD 12010'PBD - Trip out. to run CBL - MW 9.5#, Vis 36, WL 6.8. Circ 9-5/8" csg. Cemented w/800 sx Class G.w/0.2%HR-7 mixed to 15..9 ppg. Plug down w/2000 psi. ~ 9:'55 AM 3-13-73.-Packed off csg hanger, tested to' 5000 psi OK. RI w/Srl/2" bit to t2010~, cond mud to run CBL log, TBU K-17 (43-21) -COOK INLET- 50-133-~20248 (9-518" -12096.') 12120'TD 12010'PBD - Running CBL '- MW 9.6#, Vis 35, WL 7.0. Trip out w/8-i/2', bit. Ran Dresser Atlas bond log 12'000-10000'; poor bond thru Hemlock; log run 26 hrs after cement-in place.-Ran Sperry Sun gyro from '11980-2180' on 100' stations. RU to rerun. Dresser 'bond log. - K-17..(43-21)-- COOK "502%33020248 (9-5/8" 12096') 12120'TD 12010'PBD - Trip'out, LDDP - MW Diesel. Reran CBL, cement bond impr°ved,.RD Dresser~ 'ran. 8-1/2" bit & csg scraper 12010'.°Reversed~out mud w/filtere~inlet water, reversed Out water w/diesel. pOH LDpipe. ~- .- · TBUK-17 (43-21) - COOK INLET -'50-133-2.0248'(9-5/8" ~ i2o96,.') 12120'TD 12010'PBD - Testing LDDP. Ran,4-i/2" completion assembly to 11381", ROT'hydraulic packer ~ 11308' w/12 GL mandrels w/GLV .in place.. ND BOP. NU & test tree. Set pkr w/2900 psi,.held 1500 psi on csg & she~red setting'-b-!] w/ 3900 psi. Tested pkr w/1500, psi OK. RU-Dresser, test lubricator, to 2500 psi, ran 3-1/8" perf gun, positioned ~ 11423-11'443' DIL. Put on gas Tift, lifted to 1st valve, perf 11423-11~3' DIL w/4 JSPF. Flowed well 15 min, no fluid to surface. SI & P0H w/perf-gun. Ran BHP survey. Resumed gas lift. Produced 596 bbls of diesel in 7 hrs & started making some water; produced 475 bbls fluid w/30% average water, cut. Water is 1900 ppm chlorides; oil gravity 37.2°. TBU K-17 (43-21) - COOK INLET - 50-133-20248 (9-5/8" @ 12096' ) 12120'TD 12010'PBD - Testing - Tested pe'rfs 11423-11~43' on gas lift; cleaned up to 77 BFPH, 0.5% water. SI ~ 121'45 AM 3-20-73. Ran Dresser 3-1/8" pc'mr gun, perf 11858-11878'CBL = l1856-11876'DIL, lowered gun below perfs. ProduCed well 45 min. SI & POH w/perf gun. Put well on gas lift ~ 4 AM 3-20-73, testing. TBU K-17 '(43-21) - COOK' IRLET' ' 50-133-20248 (9-5/8" @ 12096') 12120 ' TD 12010 ' PBD - Testing. . Tested perfs 11423-11443' & 11856-11876'. Total 26-1/4 hfs testing produced total 2876 bbls fluid, average 30% water cut, water is 12,000 ppm chlorides. · . TBU K-17 (43-21) - COOK IR-LET - 50-133-20248 (9-5/8" @ 12096' )-..' 12120' TD 12010'PBD - Attempt to pull bottom GLV. Tested perfs 11~23-11443' & 11856-11876' 7.-3/~ hrs, produced 829 bbls fluid, average 35-40% w~ter cut, 12000 ppm chlorides. Shut off lift gas, bled dow~ csg & tbg. RU North Star WL, 'RI t.o pull bottom BLV, fluid level ~ 1500'. Pumped 175 bbls-Tiltered inlet water into csg. Latched on GLV ~ 11267', Jarred 1/2. hr, tool pulled off. Redressed & ran back, tool set down ~ 6600'. POH, had #3 GLV.-Ran & reset #3 GLV. Prep to make 1 more attempt to pull bottom GLV. The Above ~$:,Correct: SIGN~E ' ' ~ DATE District ~illing Superintendent TI TLE __.PAGENO.]'.. ~ ,,(.NUMBER ALL DALLY WELL HISTORY FORMS C~SECUTI~LY AS THEY ARE PREPARED FOR EACH WELL.) ~-17-73 3R-¢$9-2 / or ~or,ko~ operations, Il cea~inl, co~inl,, or pert~iaCinl, Ihov to~ma~i~n ceo~o aeq~n~a~ly. A~cach description of all sores. Work per- sbee~o until final c~le~ion, aepor~ offieill or representative gba~illed ~ b~t no~ less frequently then every 30 dsys, or (2)on y ~or ~orkOvars ~d ~o~'logit8 ,e~tinf of oil o~ring un~il ~:-?~- -.~.): '.-~:¥?. .... '~. :- D~ILY wILL fi[STORY - I'N ois~'ric'.~:. . $~- ~~ ....-/:::~ .;-:...;:. , ~an~y' ~ PariSh .... . ..... , _ ... -Field.. '~'~: ~~O BA~' ~ ~ase or Uni~ DI~'I~~~AMD GAS __Well Ne.'~-~T ,, , ~ , , ,~ , Da~e & De, p~h Coaple~e Record ~or each Day While Drilling or Workover in P~oSress a~ 8:00 , , , , , , ,,, , ,. '3-23-?3 ~o K~? (~3-2~.) -~oK ~~' 5o-~3-3-2o2~8 (~-5/8" 12120~D 1~20~ 12010~-PBD - Circ .~ con~ ids cut =u8. ~ ~or~ S~ ~, set ~o~ ~ ~8 v~ve ~ 996?',, P0~. ~ ~esser,. ~es~e~ lubricator ~o 2000 psi, ~Z ~ ~er~ ~ v~'3 ~oleS ~ 11298~. RU ~o circ, p~pe~ 20 ~ls ~e~ w~er ~o~ ~.. Cs~ v~ve le~e~, ~ns~le~ 'ad~ion~ v~l~e. - ~a~e~ ~e1-1 ~o~. ~t ~/?i~ ~ls o~ '~.~ ~u~, circ out ~as, oilt ~ater ~r~ cs~. ~xe~ au~ ~' c~rc ~' con~ ~u~ .no~ 9~3~ ~n,.~ ?.~-ou~. 3-26-Y3 ~o ~-~? (~3_~) -'cook ~~.- ~0-~33-202~8 (P-~/8":e ~20~6') 12120 v ~D 121~ v ~D 1~10 v~D -' ~t v/sti~er on DP. -' ~ 9. ~, Vis 39, ~ ?~ ~. - C~rc- ~ con8 ~u~. ~nst~led .B~V ~n ~er, ~D ~r.ee ~ ~ BOP. ~es~ ~~ ~o- 2500 ~s~, ~1/2" r~s ~o '3000 ~s~. '~Ze~ ~ loos.e ~/250000~, ~0~. ~ ~/ .. -' 8-1/2" ~ ~o 1200~v, c~rc ~as c~ ~u~ .~ '0~.' ~n ~ess'e~ ~ .~as~e% %o- 11900~',_'rec i ~-o~ pacier ~er. ~ ~ovco ~ re~ainer o~'~. Stuc~ ~ ~8~v , set'. i- i1~8t~ .- ~ ~esser, st~et r~in~ stin~er on ~P. 3-2?-73 ~u K_i? (.~3-2~) - cook z~ - 50-133-202~8· (9-5/8, ~ ~2096' ) 12120~D 1~20,'~ 12010~'- ~ip in-~or s~ueeze ~2 - ~ 9.~, ~is ~3~ .~ 8.2. ~e~ 15 b~l'~a~er, ~ed 150 sx Class' "G" ~/1% C~-2 ~ 0.2~ ~-?, lo re~ainer. S~ueese~ per~s 1185~'1187~ ~ ~.'~ ~in~ ~ress~e. 5000 PSi.' ~everse~ ou~ 50 sx. PO~ w/s~er. ~U ~esser, ran ~e r~n~ & J~ b~s~e~ to. 11~00v. ~an 9-5/8" ~o~co csent retainer~ sel' ~o~ t 11352v ,-~e~ up set re~ainer t 11333v. -- 3-28-?3 ~o. ~-~? (~3-2~) - 'coo~ ~ - 50-~33-202~'8 (~5/8" e ~20~6' ) 12120vTD 12120v~ 12010v~BD - ~illint ~t i 113?0v - ~ 9.5~, Vis ~0, ~ Trip in ~/slin~er ~or s~eese ~2.' Circ 1-1/2 ~rs. ~a~e~ inio relainer. w/3900 ps~. ~ZF ~/3?00 ps~ ~ 2.3 B~M. ~pe~ 9 ~ls ~a~er, ~xe~ 150 sx Class G ~/1~ ~-2 ~d 0.2~ ~-?, s~otle~ to re~ainer. S~ueeze~ per~s 11~23-11~3~, ~ ~ ~n~ ~ress~e ~00 ps~. ~everse~ ~u% 3 ~1 ~ con~na~e~ mu~. ~0~. ~a~ed o~t ve~hea~ valves. ~ bit, ~ille~ 2v o~ ea~ on to~ o~ re~ainer ~illed retainer ~ ~ ~o 113?0~. 3-2~-73 '~ ~-~? .(~3-2~) - coo~ ~a~ - 50-~33-202~8 (~-~/8" '~ ~20~6' ) 121~TD 12120~TD 12010~D - ~illi~'5~d ~ ~ 11820' - ~ 9.5~ Vis ~0, ~ ?.~. ~ille~ ~l 11370-11h5~v v/strinfers ~o 11~P5~. ~ c~ 11~95-11~97~· Tes~e~ s~ueeze ~2 ~/2900. psi ~or 10 sin OK. ~illet reiainer ~ 11~?~ ~ ~art ~ Stoa ~699-11820 ~. .- . 3'30-?3. ~ ~-~? (~3'2~) - coo~ za~T- ~°-z33-202~8 (9-5/8" ~ ~20~6')-" 12120 v TD -12120 v TD. 12010~ ~BD - ~in~ ~ - ~ 9. ~, Vis ?0. ~1t ~t ~ 11820-11858~, voit 11858-118~5v ~8 c~ 118~5-~879~ void ~o . - · PBD 1~10v. Test~ s~uee~e 2850 psi 10 ~in 0~. ~an cst scraper to 12010~· ~ ~ , The Above is CorF~ect: ,, , District ~illing Superintendent TITLE ~'~i,pAGE NO~ 6 ' (NUMBER ALL DALLY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL, ) · ~ : ' / :~:"~' ' i~ " 3B-459-2 12/67 ''. ' ' . / . : ' 'DA ILY WELL HISTORY - I.TER1Nu. I AY 4 ~ " ....' - ';~';' "'" __ ~~ORA ~ ~ , . ~ '. . - , , , ,,, ~ ',~ , , . , -Fi%Id TRADING BAY UNIT Date & Depth at 8:00 A.M. .k-2-73 ' 12120' TD k-3-73 12120 ' TD k:4-73 12120 "TD Complete Record for each Day While Drilling or Workover in Progress ~1~3U'K-17 (43-21~ - COOK INLET - 50-133-20248 (9-5/8" @-'12096') 12120'-TD t2'010'PBD - Testing - Set RTTS ~· 11792' ~ test perfs 11856-76' w/4000 psi for 20 rain OK. Test perfs @ 11423-43' w/2900 psi OK, Ran RTTS to 11950', reversed out mud w/inlet water & inlet water w/diesel. POH .& LDDP,. Ran 4-.1/2" completion assembly,-'landed ~ 11379' -w/B'OT pkr ~ 11308' w/12 GLV. ND BOP, NU tree, test to 5000 pSi OK. Set pkr w/3000 psi, sheared out w/3850 psi. Tested pkr w/3000' psi-OK. RU Dresser, tested lubricator. Ran .3-1/8" perf gun to 11800'. Put well On gas lift, produced 303 bbls diesel. Perf l~751-11771'DIL w/4 JSPF. Flowed well 12' min, SI & 'POH. RU North Star, ran BHP · survey. Produced 611 bbl in 10-1/4 hr @ decreasing rate last '64 bbt w/increasing show of crude w/.3% . water & 3% sand & 'mud. SI to l~t csg pressure build up., .Shot ~ fluid level ~' ll300'. Opened well, flui'd 'to surface ia 2 hrs.,' produced 54. bbls in' 1/2 hr w/ 0-15% w~ter & 1% sand & mud, 10,000-ppm Chl water.· .Total .recovery 991 .bbls fluid (858 bbls diesel~ 128 bbl oil-& 5-bbl water), - TBU K-17 (43-21).' COOK INLET -' 50-133-2024~ (9=5/8"' ~ 12096' ) 12120'TD 12010'PBD - Testing - Tested Bench 4 perfs 11751-11771' until l0:30 AM '4-2-73., .last rate 15-18 BPH w/5% water. Released well to Production. Dept ·~ ll AM-4-2-73. Released One rig crew ~ 12 noon & one crew ~ 4 PM 4-2-73. Perf Bench 4 11736-1t751' w/3-1/8" gun' W/4 JSPF. Produced well 1/2 hr, SI & POH. Perf Bench 4 11693-11723' w/4 JSPF. Produced Well ·3/4 hr, SI & POH. Perf final ' Bench 4 11663-11693' w/4 JSPF, produced well 1/2 hr, SI & POH. 'Began prod test of Bench 4 ~ 10:15 PM 4-2-73. Testing @ 'current rate of 1600 BPD, 0.5% BS&W. TBU K-17 (43-21)'- COOK INLET - 50-133-20248 (9-5/8" @ 12096") 12120'TD 12010'PBD - Perf & testing - SI @ 9:15 AM 4-3-73. WIH & perf l1443- l1458'DIL while flowing well. SI & POH. W-iH & perf l1423-11443'DIL while flowing well. SI & POH. Put-Bench i & Bench k perfs on test ~ 4:45 PM k-3-73. Produced at rate of' 2400 BFPD w/0.5% BS&W. SI @ 2 AM 4-4-73. WIH & perf l1607- l1637'DIL-'while flowing well. SI & POH. WIH to continue'perforating. The Ab°vel is Correct: sI~E~'-''' · / i~ i- :.i~Z;~,,;~,."' .A~ : , Distri. ct...i~ii!in~- suDer~ntend..ent TITLE paaao~l'al:I Ae(i qae3 .x%z paoaal:I a~aldmo3 -.. ' CLT, ~ '.-- . -'" 'lS'V 00:8 ~o se q:~daCl ~, a~,eQ 6'i3T. Unga~ 'O'M-. ao paPpndS .aoaeaado . . ,- :::- ,...- . _,_'.; ¥ Ovrosc~pic~~ Direction2]l__ M¢:tishot - - Su. ~ace: 2 .... ; ' - 2,Lou 11,950 -' ": "' ~ss:Ein~__ Salmon (43-21),le~ 1 co'nd'4 _wEtt-~o. ~-17 . . . . ' ' ' :'. FIELD:Trading Bay , ; . . - .. ' ' ' ' ' STATE Alaska COUNt/PARisH~Kenaz~ --' ''' ' 'oup-~u~¢~ . 8-9-57, .-: ".- '¢I . ' -' 2-2-73 ~Oa ~O sg3-1~7~ -' . .... ~ ~IL~NTIC RICHFIELD CC;,~PANY · /"., KIN$ SALMON {63-21) K-17 LEG 1 CONDUCTOR NO. 4 FEBRUARY 2, 1973 SURVEY DATE ' .NCP, TH NCARTHU'* ,.. ~,, RIVER ..................... Z ............................ , ...... .~E~TICAL_SECTION CCNPUt'ED ALONG CLOSURE- KENAI PEN[NSUL'~ OOROUGH, ALASKA ..... ~ ................ SPERRY-SUN ,.~E.LL }SURVEY l NG__.CO~.PgNY SU-3- 16131 . & ,.16778 ..... TRUE NEASURED VERTICAL DEPTH..._' ....... DEPTH ........... RECORD OF SURVEY O. O.O0 ORIGIN AT []4, 114.00 0 0 N .. _ '- .[39o ....... 138..99 ........ z ....... Oi .... 5 ...... ' ..... S ~6~, 163o99 0 5 - 189, i88,99 0 25 ' INCLINATION DIRECTION DOG-LEG .RECTANGULAR CCCRDINATES SEVERITY VERTICAL OEG._M[N DEG._] ......OEG/IO0 .... _SECT!CN _ -_NO. RYH ........... SOUTH - ......... EAST ............. CENTER O'F LEG 2 CONTROL PT 77.79 42° 22 ...... 0 .EL ..... '.. ....... 0.00 ......... 26.73 .......... .77.79 42.22 0 E 0'001:~'.~, '26.73. ' ' 77,79_ 42.22 i"" ' i ' ..' > . . ;.82--.W ' ' 0*33.,-' /~-~26.69 -77o78 ..... ~ ....... ~ .... 42,18 ............... $ 84 ~.~ 26.66 S ~9 ~ 26.59 214. 213,99 0 ;~39,, 238.99 0 10 .'. ~'..N. :2~%. _ .;,.263.99 0 5 0...5 0 5 0 0 15 '0 0 289. 288.99 314.._L. 313.99 339. 338.99 .' _..__'_36t~.-'f "!~63.9g. ................ _~_' ~__~ O0 · ........ 399 425, 424.99 ...-.' .. 0.33 ""-.0'33 77.78 42.14 77.71 41.97 26.z~0 26.32 26.22 77.'71 - 41.86 77.72 ' 41.79 7.7 o 74-] ..... ::--- .... ':-.41.68- N 84 ~ 0,66 26.18 N._86--W-"~. --0o01 .: '-'-26.14 N .9 E O.4g 26,14 __S-.-89--E O, 70 .... ' 26.2 [ S 73 E 0,28 26.37 S 0 E 1.00 26.37 77°74 77.74 77.78 77.73 77.73 41.65 '41.61 ~ 4t,62 --41.69 ..41.84 -) qO0. 4~9.99 0 q75 · 474.99 0 .500. .... ~ ...... 499.99 ............. 0 525. 524.99 0 550. 549.99 ................ 0 575. 57~o99 0 600,, .......... 599.96 625. 624.91 650. 649,,83 lO N 10 ~ 10 N 9 E 15 ......... N_.38-E 3o .......... _.N e 50 S 70 E 45 ...... S 60 E 40 S 61 E 35 S 63 E 0,66 26.34 77,80 . '41,83 0.22' 26..3~ 77.87 ' 61.84 O. 52- ..26.3g-- 7.7.96 4,1.g 1 1. o .9 .......... 2 6.7 o ............. 7 8. o 6 .... . --' ............... 7.73 ............. 28~ t9 ............ -77.34 .....&i:~r;.~--v-: ....... :-43,-6~,L:~t~-~;~ .......... 3.67 29~71 76.56 4'5"~ Q2 ...... 3.71 3!~63 75.66 ~"" ~z~i ':' ...... ..................... ,, PAGE 3-2 .. FEBRUARY '2~ 1973 SURVEY DATE 1) K-17 LEG I CONDUCTOR NO', RIVER ..................................................................... PENINSULA 8OROUGH~ ALASKA ............................... SPERRY~SUN _t~ELL. -.SU~VEY,[ NG ....COMPANY .- RECORD VERTICAL - SEVERITY · RECTANGULAR CaORDI NATES" ...MEASURED YERTICAL _DEP_TIt ..... -'--_;_DEP. TH ..... _, .......... LDEG_HIN.. DEG ....... DEG/IO0 .~LSEC.T,[ON~~OgT. ----SOUTH- -t 675. 67q,71'""~.'~'. 5 ~0: ' $ 67' E~ ~,56 .:..34,05 7~,69'.. '" ~.~;.--<~ ~9,07 · .' ' . ' = · .~.':>'. ": ' . ,.'::,,. ;'.'.' . c, .': . . L: ' '. , .;'=,~,, '- "." ~:. '.:":/:'7.L" ."' :/'=,:..:'. J;: ' .' .. . . .- 1050oi_' i0~+ 1..78 .......... 1%-~0 " ..... S '/5 E.. " i'10 96,,,0? · S-?4.-E .... 1-57. _!i _'- .. :":'": ,. :,. :~.:.. ~- r;: ;i.: .. ~. , S ?~.E " 2,00 121.85 .. _.~]..S·..'/~ E 2o551 ':'----1~6,~ 18 S 73 E 2, 16 15 ,.:' . ~._ S ..-72.--E --.2oql- 167+56 S 72. E 2,49 184.73 ........ S ?2 E 2,50 202,92 57.6.7, i.,:'~: ~:'.'"<~:;' i08o96 -. 50,54 133,83 66.32 ' '-147,6~ 61,85 ' ' ~62-26 ..: -.... . . . 36, 82-' 17.7,~4 3I.~7 194,20 25,80 211,6~ S 7i E S71 E S _71. E 1550. 1507.75 26 35 $ .71 1600o....--_1551.97 ............. 27 50 ................ $ .. 7), 1650. 159~.59 29 15 S 71 1YO0 ..... 1638o64 .... - ...... 30 35 .............. S 71 1750. 1681.11 31 50 S 70 1~00. 1722.97 33 10 S 'fO 2,61 222,06 19,51 - 229,91 2,83 242,32 12.85 249,26 '. 2.50 =.- 263 oS'Z-- --5.86 269.55 · . . E 2.33 285.72 -1.62 290.7t. -9.02 ...... 312.78 2.66 l'iO0. '~1089,97 15 30 1150. 1137.84 .................. 16,45 1200. i185.~4 17 50 .. . 1250'. '" 12a2~'.72 lg'--..O 1300. 1279.63 20 15 (PAGE 3 FEBRUARY 2, 1973 SURVEY DATE .--.VERIICAL..SECTION-.CC~qPUTED.ALCNG CLOSURE S U-3-.. ! 6131-&-... 167.7.8 ......... RECOP, D OF SURVEY TRUE INCLINAT ION DIRECTION DOG-LEG t~EC T/~NGULAR CCCJROINATES EE~SURED VERTICAL SEVERITY VERTICAL ..~EP.T.H --_.DEPTH ................... OEG.....HIN DEG...,_' ..DEG/IO0 ..... '._SECT10N,~.~ _NO~TH.,__SOUTH .......... EAST.-, .....b~EST .'~ . . ' 34 35 '"']:}:'~: '~S 71 E 3°04 439,36 36 25 "S 70 E. 1o66 .497,40 36.25 .....~S.L~O.-F. 0~00' ,L-.526,7I- ~5 20 $ 70 E 2o16 · 555-26 35 50 S 70 ~ ' 0,99 .. 584,17 -52,87 437,26 · '-62.82 ...... :46Z~o 60 -72.97 492,49 -93.01 5~)7,55 .. -103.02 :.575-06 1850. ',:'i 176~.13 1900..~_1804' 80 1950. 1845o03 -. 2000, .... ~..1885 o 2 7 2050° i926.06 2[00o ' X966.60 2.! 5O o 2180, 2030' , - ARE BASED ON THE USE OF THE TANGENTIAL ,~, THE CALCULATIQN PROCEDURES -~ i: - ~ ' '~': '!" ' --__HgR I ZONTAL O ISPLACE~IENT..~.=-.~-L632- 19.._F. EET....AT.-$OUTH---LTg.~fiG* :..' . 5..-.gl No ..EAST (.TRUE . ~ . ~ .~.. } . . :~; '.. .-... . : .. . OIL ATLANTIC RICHFIELD COMPANY PAGE 1 KING SALMON (43-21) K-XT.._. LE~,_..!_.~O..N..'.D.~.G.T~.OR_~N~.? ~ ................................................. MARCH...I~, 1973 .............. SURVEY DATE NORTH NCARTHUR RIVER VERTICAL SECTION COMPUTED ALONG CLOSURE KENA[ PENINSULA 80ROUGH, ALASKA SPERRY-SUN WELL SURVEYING COMPANY SU-3-16785 RECORD OF SURVEY TRUE "[NCL [NATION DIRECTION DOG-LEG RECTANGULAR COORD ZNATES MEASURED VERTICAL SEVERITY VERTICAL. , 2]80. 2030.12 ORZG[N AT._CENTE_R_ q..F__...LEG _2 _.CflNTROL PT -1].9,66 ......620,.7_6 2200~' ..... 204.5~60 39, [5 S 70 E 0.00 524.73 -123.98 632.6.5 2300. 2[20.40 41"35 S 70 E 2,33 584.07 -146,68 695'0[ 2400. 2194.15 42 29 S 70 E 0,90 644,46 .-169,78 758.48 2500. 2267.28 43 0 S 70 E 0.5! 705,44 -193.11 822,57 ........ _2600, ..... Z3~O,.O. 2 .......... -._~ ~._ZO ......... S_..70... E .... .0..,~_ ~_ 7..66,.80 ..... _~.2 t 6,58.~.B87., 05: 2700. 2413.[6 43 0 S 70 E 0.33 827.77 -239.90 951.14 ..28 O0 · ........ 2~89 · XQ .... _~0...~ $ ............ $. 6 7_ 5 ............ 3,1 ~..~ ...... 887,3.8._~ ,265.32._10 L 1.02 2900. 2566.47 39..19 S 65 E 1,80 9~6.29 -292.10 1068.45 3].00. 2720.35 40 0 3200o 2796.3[ 40 34 3300. 2871.59 3~00o 2946.02 ....3, §.QO..,+. ._~.0..[9'7 [ ,, .$._6,1,.:_.[:; _1-..,~0.. _[006:.45,. S 62 E 0.60 [067.37 S 62 E 0.56 !].29.00 -321.90 .... 1124.,~9 -352.08 1181.24 -382.61. 1238.6'/ S 62 E 0.59 1,[9[.39 -413'5[ ..... 1-2'96-79 S 6]. E 0.98 1255.04 -4~5.89 1.355.20 $ 6t._...E_ 0.63 .[.~..!9.,.fi...8_ -4~8,66. ....1414.32____ 3600. 3092.67 4:3 9 ...3700, ....... 3165.1l 43 _35 3800. 3236.94 44 _3900. .... 3310o tX 4000. 3384.95 4100. 3460.46 3686.26 S 61 E _S 61 E S 6[ E 41 33 aO 58 _S...56 S 50 S 48 0,61. 1384.67 -511.821474.14 0.43 i450.38 -545.24_ 1534.43 0.49 1516.69 -578.97 1595.28 41 41 2 14 16 S 47 S 47 S 47. 0.19 1845 74 A~C~.~ -793 31 1847.54 ATLANTIC RICHFIELD COPtPANY P~.GE 2 NORTH MCARTHUR RIVER VERTICAL SECTION COMPUTED ALONG CLOSURE KENAI PENINSULA BOROUGHt ALASKA SU-3-16785 SPERRY-SUN WELL SURVEYING COMPANY RECORD OF ,r TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR CC}ORDINATES ME AS UREO .....YE RT ! C A L SE VER IT Y-_i_:¥E R TI.C_AL DEPTH OEPTH OEG MIN DEG DEG/[00 SECTION NORTH SOUTH EAST WEST 4500? ..... 3761.25 4600., 3836.15 4700. 39].]..41 4L 30 S 46 E 0.66 2043.78 ~.]. 1.1 S 46 E 0.31 2109.56 -929.44 1991,82 -975.18 2039.19 4800. 3987.07 40 50 $ 46 E 0.34 2174.88 -1020.60 2086.22 ~900. /,063.67 40 0 S 46 E 0.83 2239.09 -1065o25 2132.~6 5.0_00..~ ~[~0...~.7 ,39_5~_. S.:~6,.,.E_' 0.16. ~ 2,~.0~...,.0.8 -1L0.9.7,5 ..... 2[7.8..5~_ ._~-'~ ' ..... _~ ~ .: 5100. 4218.09 39 S S 45 E 0'98 2366,10 ..5200, ~295.,68, .39 ..... 7 _S ..~5 E ....... 0.,.03. _2~29,,[T 5'300. '4374.22 38 14 S /+4 E i.08 2491.05 S 44 E 0.08 2615.43 S 43 E 0.72 26'77.16 -1154.33 22.23' 12',i*~'~,~,~ - 1198.94 _..2267 ..7 3__~'~'i~<'~ ...... -1243.~6 2310' 72 ,.1288.16__2353,.88 -1332.94 2397.13 -1378.08 2~39o22 5800. 4767.83 37 50 37 30 ~7__.~ 3_ .... S 43 E 0.28 2738.49 S 43 E 0.33 2799.37 __.S.__~ ~.,__E ....0 _. 6. ~__ .2 8 60 · 0.7 -1/+67.46 2522.57 ,-_1512.58 .... 256~.20_. 6000. 4927.93 36 15 _6100. ..... 5009.09 35 ~5_ , 6200. 5090,94 35 4 $ 42 E 1.13 2919o18 S_.~I E 0.77 ........ 2977.55 S ~l E 0.68 3034.96 -1556.52 2602.77 -1600.62 2641.10 -1643.98 2678.79 6300_... · 51.72.5B 6~tO0. 5253.83 35 6500. 5334.14 36 6600. 541q.01 37 0 6700. 5~93.34 37 30 .... 6800. ......... 5572- 23 ......... 37 _.S 5 ....... __S_.~.O__E .... S 39E S 39 E 0.70 3[~ .L~3t~-l~ U~L~ 1~:733.52 2752.60 ~ - ~' ...~ ................. ............. S 3 ~--'E 0~73 3270.04 $ 37 E 0.78 ~L;Sa ~'" OH, AH, g ~7S.86 2863.78 s ~7 e ...........o.,~ ........... ']~.~fg~ORAg~ .... ,192~.9& .2900.76 .,. ATLANTIC R[CHFIELO CCINPANY PAGE 3 NORTH NCARTHUR RIVER VERTICAL SECTION CCHPUTED ALCNg CLOSURE KENA[ PENINSULA 80ROUGH~, ALASKA SPERRY-SUN WELL SURVEYING COMPANY SU-3-16785 REC,Q. RQ_~,~_ SUR YEY TRUE INCLINATION D/~RECTIQN DOG-LEG · ~EASURE.D___ ~ERTICAL ............................................................................. SEVERITY. ......... .V. ERT!CAL DEPTH DEPTH DEG MIN -OEO OEG/t O0 SECTION 6900°__5650.85 _ 7000,,, 5729.66 38 0 S 36 E 7].00,,, 5808.38 38 4 S 36 E 7200. 5887.4~ 7300. .5966.27 7~00 .__~ 60..~ 5.25, 7500,. 6124.23 .7600.. 77 O0 o 628 ]. ° 7 t, 37 46 S 36 E 37 58 S 35 E RECTANGULAR CI~ORO[NATES NORTH SOUTH EAST NEST 3"'/' 50 $ 34 E 38 2 S 32 E 0.63 35~4.08 0.06 3575.22 0.30 3635.96 0.64 3696.82 ____0.,62 ......... 3757,.33.__ O.CtO 3817.85 __ O. 66__h3 878.51._ 0'61 3938.91 -2024.10 297~. 14 -207~.98 3010..38 -2123.53 3046.38 -2173.92 3081.66 ~.222~ .77.,_3 ].[5,, 9.6 -2275.62 3[50.26 -23Z7.3 5.__~ t83.8 5_ -2379,,60 3216.50 7800.,.~.6.360.,..96 ~7...._3...5_ 7900,. 6441.08 36 45 8000. 6522.39 35 36 _-_2 ~3 0.. 76 ..... 32~9,,,.72_ -2~8!.50 3281.43 -2530.86 33].2.28 8100. 6602.86 36 25 S 31 E 1o00 4172.60 -2581.75 3342.85 ;8200. 6683.49 36 ].6 8300....:. 6763,...96.~ S 32 E 0.6]. 4230.59 -2631.9[ 3374.20 -.26.82.,26 .... 3~05,,66 8400. 6844.02 36 49 ~500.__6924.59 36 ..... 19 8600. 7005.07 36 25 S 32 E 0.39 4347.53 S..._32 _.E O. a9 .....~405.59 S 32 E 0.10 4463.78 -2733.08 34:37.41. -_2783.30 ._3468.80 -2833.65 3500.26. 8700~____.__708 5. 97 , 3 6~0 8800. 7166.96 35 55 8900. 7248.45 35 25 9000. 7330.12 qlO0o 7412.25 _9200. ..... 7494.91 . 34 47 S 34 15 ................ S y~' ~.,,~ d ~';'h ~ ........................... 30 E 0,46 47~.4'D]Gi..'H Cf Oil. ~.~~.8~ 3648.85 ATLANTIC RICHFIELD COMPANY _ ___KING SALMON.. (43-21). K.~[~7 ...... LE.G ~[_.CQN. DUC.!O~_.HO,,~_~_ NORTH MCARTHUR RIVER KENA~ PENINSULA ~OROUGH~ ALASKA PAGE 4 NARCH.~.I,.~, ...... ~g73 ............... SURVEY_ DATE VERTICAL SECTION CCNPUTED ALONG CLOSURE SPERRY-SUN WELL SURVEYING COMPANY SU-3-[6785 RECORD OF SURVEY TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR COORDINATES MEASURED_ _VERTICAL SEVERITY .... VERTICAL_, ..................... ~ ................................................................ i_i DEPTH DEPTH DEG MIN OEG OEG/[O0 SECTION NORTH SOUTH EAST WEST g~o0.. 7660.7[ 9500. 7742.63 34 S S 28 E 0.58 4909.76 35. 0 S 28 E o.g[ 4965.06 -3229,,86 3730.35 -3280.5]. 3757°27 9600. .782~-28 35 [6 S 27 E 0.63 5020.45 -3331.95 3783.49 9700. 7906,.31 34 53 S 2"/ E 0.38 50'/5.32 -3382.9]. 3809°45 9800.. '''~..988.'~.,'~7_ .L....~.~,~L/~r...L~,.~.,__~.~....:-- S...-..27,..E--- ....... 0,,,..1,3. .... '.5..13..0,.00__ __ ___. __--3433,,70 ....... 9900. 8069.46 35 55 .. ,10000. ....... 8].49.24 .......................... :37 ].0~00. 8228.02 38 I S 27 E 1.16 ' 5186.28 S 27 E .................. 1,,,16.. ..... 52~4.12 S 27 E 0.93 5303.21 -34.85.96 386[.96 -3539 o69. 3889.33 -3594.56 3917.30 $.,.27.,.E ....... [. 08 ....... S 27 E 0.16 5424.43 S 26 E 0.65 5484°59 jim ~.3650~. 76,_3945.9.3 -3707.15 3974.66 -3763.82 ~002.30 10800. 8765o13 4! 18 S 26 E 10900. ..... 8839.35.. 42 5___ S_26 E 11000. 8913.17 ~2 25 S 26 E 11.t00. 8987.95_ AL.36 S_., 26._.E 11200° 9063°80 40 60 S 25 E 11300. 9140.37 40 2 S 25 E 11~00. 9218o0! 39 4 S 25 E 11500o 9296° 72 38 5 S 24 E 11600. ....... 9375.26 ..............38 15 ................. S 24 E -3821.09 4030.23 ]:: -3878°96 ~058.46 =.3937.63, ._.~0 8 ATLANTI~ RICHFIELD COMPANY .K ING....,.$ AL MON (.~ 3...-.. 21. )_ K.-..X.T... '_.L. EG_._L._~.O. NOUC~Og_ .NO el._~ NORTH MCARTHUR RIVER KENA! PENINSULA BOROUGH, ALASKA . . PAGE 5 ................ ..P,.A~CH~.....1.~ ~ [973 ............... SU.RVEY.. DATE VERTICAL SECTION COMPUTED ALONG CLOSURE SPERRY-SUN WELL SURVEYING COMPANY SU-3-I6785 .... SURVEY TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR COORDINATES ;~" , ..MEASURED ...... _¥ERT ICAL SEVERITY ....... VERTICAL DEPTH OEPTH OEG MIN DEG OEG/IO0 SECTION NORTH SOUTH EAST WEST 11800o. 953[.92 38 17 S 23 E 0.69 633g.g5 -~STS.ST 4385.26 11980. 9673.01 38 40 S 22 E 0.62 6444.02 -4682.51 442'7.13 · ~a ,, _ILH E_...C ALCU. L AT.I..O N__._P B OCEDURE $._.AR E ... B AS ED.._.Q.N_.T t! E_..U S E._. 0 E_.T H E.._T.A..~G E NT.I.A L._ OR_.CH OR HORIZ(]NTAL DISPLACEMENT = 641~o02 FEET AT SOUTH 43 DEG.. 23 HI.N. EASTITRUE) ' REPORT and P~N SUB-SURFACE SURVEY ATLANTIC RI.CHFIE LD TRADING BAY UNIT K KING SALMON PLATFORM CONDUCTOR No. 4 CO -17 e I R E C T I ICI ~ A L S U R V E Y ~EPT:H A~GLE iD TVa SUB SEA' ¢ ,0 O0 ? 7 2~t,N SE EPTN AWGLE GIRECTXON 2100 3766 O' $ 72E s lO~l,?8 S GE S 70E S E l 8 ,4 7 ~N tE ~8 S 4~ 42 45' 1017.6'/ S 6q,4OE DIV:$1ON CF OiL AND GAS ANCHORAGE O 6 8~ 0,86q . . 16!0.6i O ][ ~ E~ C T I 0 N A L S U R V ~ ¥ TYD SUB SEA c ~ 'o s u ~ e's ~0 7 ~ 23 ,38 ~ S S . 37 ~ $ ~ $ iE S ? ,o ? ,0 ~20:i 8126'.77 ! 11 I ?:, ?ce O, CLOSURE e5??.15 S ,e'" i2' E EVEN :]LQO FEET (::]:F SL~B $,E~i DEPTH 200 1300 *00 500 · ?0o ~2 io 18 21~2 ZBO~ 2637 3332 3466 3603 200 ,00 ¥0~ o o0 o0 o0 oo oO O0 ~N S its ~416'~62'S o 0 ~aOO,O0 2900.00 ~4 38,75 8 SUB SEA O~PTH TVO T~ TVC $ . . 6077 b2~2 632~ ~; ~OO 6575 6a99 5500. O0 6825 :~'~00'0~ 69~z 7077 5800'00 7204 5900.00 7330 6000 7456 6lOO.O0 O0 5600'00 5?Oa'oo ~eoO:;Oo 6o0'0'oo0 ~2 ttqm l 2 t2i~ ~ . 1.~30 13S6 25 26 f~/!AY 4 1973 DIV:$1ON CF OIL AND GAS ANCHORAGE ,? SUi~ NCE ~es 3$ 31 DIV:5!C/N CF OIL AND GAS ANj'tOR K,[NG SaLI~N TVO T~ 05 MAY FEET OF ~EASURED DEPTH ~0 ~0 ?~ f6 Ah~CHORAG~ AtlanticRichfieldCompany North American Producing Division North Alas~-~'~strict Post Offic(~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 4, 1973 State of Alaska Department of Natural Resources 0il and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. Homer Burrell ~: Well K-17 (43-21) Permit 73-01 ~ Gent lemen: We are enclosing the Monthly Report of Operations for March for the above mentioned well. Very truly yours, ~TL/W~a/ll Enclosures APR 6- Ai-~CHORAG~ Form No. P--4 REV, 9-30-6~ STATE O,F ALASKA SUBMIT IN DEPLICATE O~h AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F :DRILLING AND WORKOVER OPERATIONS ~. API NUMERICAL CODE 50-133-20248 6. LEASE DESIGNATION AN'D SERIAL NO. ADL 17594 T. IF INDIAN, ALOI 1~ OR TRIBE NA.AIE 1. O IL ~. G AS [] OTHER WELL ~ WELL 2. NA1VIE OF OP]gRATOR 8. I/NIT,FAi~M OR LEASE NAAIE *Union Oil Company of California Trading Bay Unit 3, ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage ~ Alaska 99501 4. LOCATION O,F WELL Leg 1, Conductor 4 694'N & 85'W fr SE cr of Sec 17, TgN, R13W, SM 9. %VELL NO. K-17 10. FIELD AND POOL, OR WILDCAT Hemlock 11. SEC., T., R., M., (BO/TOM HOLE OBJECTIVE) Sec. 21, TgN, R13W, SM 12. PEFdVIIT NO. 73-01 13. REPORT TOTAL DEPTH AT END OF MONTH, C~LaffqGES IN HOLE SIZE, CASING AND CE1VIENTING JOBS INCLUDING DEPTH SET AND VOLU1ViES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CI-IA~G~ IN I-IOL~: CONDITIONS. Drilled 12-1/4" directional hole 10981-12120'TD on 3-ll-73. Ran DIL 12064-2184'; Sonic 12064-2184'; FDC 12060-8900'. Ran 306 jts 9-5/8" 43.5# and 40# RS-95 buttress csg, landed at 12096'. Cemented w/800 sx Class G w/0.2% HR-7 mixed to 15.9 ppg. Hung csg and tested to 5000 psi OK. Ran CBL 12000-10000'. Ran 4-1/2" completion assembly and set pkr at 11308'. ND BOP. NU and test tree. Perforated l1423-11443'DIL. Put on g'as lift and flowed well 15 min. Ran BHP survey. Cleaned zone up and tested at rate of 1848 BFPD w/0.5% water. Shut in well and ran 3-1/8" perf gun. Perforated l1856-11876'DIL. Put well on gas lift with well producing 2876 bbls fluid, average water cut 30%, water 12000 ppm chlorides. Loaded well w/744 bbls of 9.4# mud. ND tree. NU BOPE & tested BOPE. Set retainer at 11686'. Stabbed:' into retainer, squeezed perfs 11856-11876' w/150 sx of cement to final pressure of 5000 psi. Ran retainer to 11333'. Stabbed into retainer to squeeze perfs 11423-11443' w/150 sx of cement to final pressure of 4400 psi. Drilled out upper retainer & tested squeeze job to 2900 psi OK. Drilled out lower retainer & tested squeeze job to 2800 psi OK. Ran & set RTTS ~ 11792'. Tested perfs ~ 11856-11876' to 4000 psi 20 min OK. Tested perfs ~ 11423-11443' to 2900 psi for 11 min OK. Reversed out mud w/inlet water. Reversed out inlet water w/830 bbls diesel oil. Running completion assembly on 4-1-73. 6 - i 73 * Atlantic Richfield Company, Sub-Operator DI~:;t~,N CF OIL AND GAS ANCHORAGE 14. ! hereby ~ that the~reg~ing is true a~d correct S~SN~O ~/~~./~.,.,~l.~,,~ =TLE Dist. Orl¢. Supervisor DATI ~'NOT£~Report on this ~orm i~ require~ for each calendar month, regardless of the status of operations, and with the Division of Mines & Minerals by the 15th of the succeeding menth, unless otherwise directed. Form No. 1=---4 REV. 9-30-67 STATE OF ALASKA OiL AND GAS CONSERVATION COMMITTEE SUBMIT L~ DEPLICATE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS 1. 0IL ~ GAS ~-~ OTHER WELL -- WELL 2. NAME OF OPE~.ATOR * Union Oil Company of California 3. ADI~i~ESS OF OPEI~TOR 909 West 9th Avenue, Anchorage, Alaska 99501 4.LOCATION O'F WELL Leg 1, Conductor 4 694'N & 85'W fr SE cr of Sec 17, T9N, R13W, SM AP1 NU~{ERICAL CODE 50-133-20248 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 IF INDIAN, ALOI 1~. OR TRIBE NA~IE 8.LrNIT,F.~:~M OR LEASE N.~ME Trading Bay Unit 9, WELL NO. K-17 10. FIELD AND POOL, OR WILDCAT Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 21, TgN, R13W, SM 12. PERMIT NO. 73-01 REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN I-IOLE SIZE, CASING AND C~WIENT1NG JOBS INCLUDING DEPTH SET AND VOLUME~ USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS, JLrNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CH.A~g~ES IN HOLI~ CONDITIONS. Tested manifold valve and rams w/5000 psi; Hydril w/3000 psi, all OK on 2-1-73. Tested 13-3/8" csg w/1500 psi OK. Drilled out float at 2100' and cleaned out to 2247'. Drilled to 2257'. Tested shoe w/equivalent 0.55 psi/ft pressure gradient. Ran gyro survey 2180' to surface. Drilled 12-1/4" hole 2257' to 2765'. Directionally drilled 12-1/4" hole 2765' to 10,981'. Drilling ahead on 3-1-73 at 10,981'. NOTE: BOPE Test as follows: Tested rams and choke manifold to 5000 psi and Hydril to 3000 psi on 2-11, 2-16 and 2-23, all OK. MAR g- * Atlantic Richfield Company, Sub-Operator · 14. I hereby t~t the is true and correct Dist. Drlg. Supt. DA're SIGI~ TITLE 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 15th of the succeeding menth, unless otherwise directed. ~o~No. p_~ i c. EN~ J R~V..-~7 STATE OF ALASKA suBMrr z~ ~L~C~ ~ OIL AND OAS CONSERVATION CO~I~EE 50-133-20248 - ' , , , I ' MONTHLY REPORT OF 'DRILLING ~. L~SE DESIGNA~ON A%'D S~[J L N~. AND WOR'KOVER OPERA, IONS ~L - 17594 Union Oil Company of Ca!ifo~ia . Trading Bay ~it 3. ADDRESS O~ OP~TOR 9. W~ NO. : :-]~' '~ j' ~fl~ w~t q.h ~,~,,,~ ~cho~a~e. Alaska 99501 K-17 (44-21) Leg 1, Conductor 4, 694 'N & 83'W from Sg co,er of n. s~c.. r.. ~.. ~.. mo~o~ no~ Section 17. TgN, R13W, S M. °~~ ' SeCtion 21, T9N, R13W, S. M. 73-1 , ,, , , ~3. REPORT TOTAL DEP~Fi AT END OF MONTH, CI-IA~NGES IN HOLE SIZE, CASING AND CEIVIENTING JOBSINCLUDING DEPTH SET AiN-D VOLU1VIES USED, PERFO-B-%TIONS. TESTS A_N-D RESULTS. FISHING JOBS, JLrNK IN HOLE A_ND SIDE-TRACKED HOLE AlxrD A_NY OTHER SIGNIFICANT CI-IA-N-~ES IN HOL~ CONDITIONS. , # ~udded TBUS t.~ell K-17 at 6:00 ant, 1/26/75. Drilled 17 1/2" hole to 600'. Drilled di~e~tio-~{ali2-1/4~r hole to 224~. Opened 12 1/4" hole to 17 1/2" from 600' to 2246'. Ran 54 joints of 13 3/8" 61# K-S5 Buttress casing and set at 2183'. Cemented with 811 sacks of class "G" w/10% gel and 2% CaC12, followed by 560 sacks of class "G" neat. Removed 20" hydril and riser. Now: Installing casing spool and BOPE. Atlantic Richfield - Sub-Operator. 14. I hereby District Drlg. Supt, oA~, 2/12/75, . NOTE--RePort on this form is required for each calendar month, regardless of the status of operations, an~ must be file~ in duplicate with the Division of Mines & Minerals by the ]Sth of the succeeding month, unless otherwise directed. / ! .t~ 11, ~: Tradll~g 8t~ Unit t~. ~le $. Blister Sion 0ti ~o.. of ~allf. ~ge, A taska -9950l Enclosed is the app~ alp-ptlcatto~ -for permit ~o drl I I the :referenced ~etl, on or al~aut January 15, 1973, aY s location from the King Salmon platform at a location in Trading Bay Unit. l~etl sampt®s and core chips are not requlr~d'. A direct-tonal survey Is requl red. the event of sus~l~ or abandonment please give thls office adequal~ advanoe notifier!on so that we may have a vltness present. Very truly yours,. ~r L. 8urret I, Chairman ALASKA OIL A~IO ~$ COH$~ATI~ ~ITTEE Encl~e cc: Oeportmeflf o~ Fish -and -Ga.~, Habitat Section ~/o enct. Depa~ of 'Environmental Conserver ion ~/o eric i.. Union Oil and Gas D~ion' Western Region Union Oil Company o, California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 unl. n January 4, 1975 Mr. O. K. Gilbreth Division of Oil 6 Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Re: TBUS Well #K-17. Dear Mr. Gilbreth: My apologies for the oversite on our part of omitting the "Reason for Drilling" on the State P-1 Form for TBUS Well #K-17. Our Reason for Drilling is to provide a replacement well in a more suitable structural position for the TBUS #K-4, which is now non-productive. Please attach this to the P-1 Form previously submitted. JRC/sk Enclosure ry truly yours, Jim~ R. Callender District Drilling Supt. Union Oil and Gas D~ion' Western Region Union Oil Company oT California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 union December 27, 1972 State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Well Trading Bay Unit K-17 Gentlemen: Enclosed is an Application for Permit to Drill the subject Trading Bay Unit Well along with Union's '$100.00 check as a filing fee. In compliance with Rule 5 Conservation Order No. 80, Union Oil Company of Ca]ifornia, as Unit Operator, requests approval of the application. The Trading Bay Unit participants, who are the only affected parties, have been notified of the location of this well. Very truly yours, UNION OIL COMPANY OF CALIFORNIA Unit Operato~ ~. ~ WSM:jb Enclosures cc: Management Committee Trading Bay Unit, w/encl. Form P~I l:t~V. SUBMIT IN ?RI/~'ATE, (Other instruet~o. reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION ,CO!MMITTEE "APPLICATION FOR PERMIT TO DRILL, DEEPEN'~ OR PLU~i BACK la. TYPI~ OF WOItK DRILL ~ DEEPEN [~ PLUG BACK [~ b. ?yPl~ oF W~LL OIL ~ GA8 ~ 8INGL, [~ MULTIPI,~ ~_~ W I[ LL: WELL OTHIJR ZONB ZONE 2. NAME OF OPERATOR * Union 0il Company of California 3. ADDRESS ~ OP~TOR 909 W. 9th Avenue, Anchorage, Alaska 4. LOCATION OF WELL Atsur£ace Leg 1, Conductor 4, 694'N & 83'W from SE cor. of Sec '17, TgN, R13W, SM At p,'ooosed prod. zo,e 1.500'N & 1120'W of SE cor. Sec 21, TgN, R13W, S. M. (Hemlock) ':--,.'~ 13. DISTANCE iN MILES AND DIRECT!ON F.IOM NEAHEST TOWN OR POST OFFICe* 24 miles NW of Kenai 14. BOND INFORMATION: TYPE Statewide Surety and/or No. Federal 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 1,500' 18. DISTANCE FROM PROPOSED LOCATION* Insurance Co. #8011-34-40 i lS.NO. OF ACRF~ IN LEASE ! ~. PRb~S'~D'D~ ! 12,120' / 9,225' (TVD) APl #50-133-20248 5. 6. LF.~SE DESIGNATION AND SIgRIAL NO. ADL 1 7594 '/. IF INDIAN, A/J~E OR TH/BE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. K-17 (44-21) 10. FIELD AND POOL, OR WILDCAT Hemlock~ Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. Sec 21, TgN, R13W, $.M. ,,..-.o-,,t $1 00,000.00 17. NO. ACHES ASSIGNED TO THiS WELL 80 TO N~^SEST WELL D~,.LING. co~P~.ET~O. 20, ROTARY oR c.sbs Too~s OR APPLIED FOR, ~. 1,230' Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) ~. APPHOX. DATE WORK WII,L, ~TART* ~. ~0_0' KB January ]5, ]gY] : ~ : PROPOS~ CASING ~D CEM~NG ~ROGR~ .. , , SIZE OF HOLE SIZE OF CASING ,WEIGHT PER FOOT GRAK)~ S~'qG DEPTH QUANTITY OF C]JMEN~ ~0" 24" 110~ X-52.. 382' Circ to.surface 17~" 13-~/8" ~1~ K-~ .... 2100' Circ to surface w/1440 sx "G" c~ ~i)~i~ '~-- "q'q/fi" ~_q 40~- R~- 1'210~ i~ ~ith' 1st 10~ ,,, - -' - ,- ]', ~1 w/~qO:sx "~" ~mt~l ,, ~ ~ We propose to direct onal drill from 600 to TD @ 1'2120'+. The angle will build to 380_+ at 2-1/2°/100'. The top of the Hemlock will be 9225'+TVD with TD @ 9805'-+TVD. We propose to use a 20", 2000 psi WP annular preventer on the ~4" conductor while drilling 17-1/2" hole to 2100'-+. There will be 13-5/8", 5000 psi preventers on the 13-3/8" casing. Bottom Hole Location: l120'N, 7201W of SE cor. Sec 21, TgN, R13W M. ~N ABOVE SPACE DESCRIBE PROPOSED FRO~RAM: If pl~po~ll i~ to deepen or plug back, give subsurface proposed, n~w productive zola. If proposal is to drill or d~pen direetZonall¥, give pertinent data on dIta on I~t~[~$~ui~iv~ ~d~ true ve,..~a! ~pths. Gi,ze~ll~vo,t preventer ~ram. ' ~.': ~-,¥ cZ,:.,, , --------- s,?rr~.,~'~].~~'/~/~~:~l-- ~'V~ December 27, ,972 - T- _ 4/. ~. _ /'. . , . ,,..,,..,:,.~. Landman (This space for State office use) CONDITIONS OF APPROVAL, I~ ANY: J SAMPLES AND CORE CHIPS R.EQUIP,~:D ~ I~U~S: [] ~ ~,o DIRECTIONAL SURVEY YES [] NO See Transmittal Letter A.P.L ~CAL CODE · January 1,1,~ 1973 ~.~Januarv _11,. 1973 0 ~,00o 2000 ~°°° o /2, o~ 0 I0O0 JV ARCO ,........__.~__.~ i NG SALMON PLATFOR¥ K-6 ARCO i~ MCARTHUR RIVER K? 13 ! T 9 G-19 17594 K-4- HEM/o.,, K- t7 1~4§0 TVD 9225 PBH \ TVD ATLANT lC R ICHFI ELD , G_5 G -4 G-32 UN ION- MARATHON ADL 18730 UNION WELL LOCATION MAP ARCO SUB-OPERATOR TRADING BAY STATE (44-2 I) 0 2000 SCALE, I"= 200d [ _. I K -17 NOV 14, 1972 CHECK LIST FOR NEW WELL PERMITS Lease & Well No. 1. Is well to be located in a defined pool ................. 2. Do statewide rules apply ........................ 3. Is a registered survey plat attached .................. 4. Is well located proper distance from property line ........... 5. Is well located proper distance from other wells ........ , . . . Yes No Remarks. 5. Is sufficient undedJcated acreage available in this pool ........ ?. Is well to be deviated ......................... ). Is operator the only affected party ................... Can permit be approved before ten-day wait ............... 10. Does operator have a bond in force ...... .' Il Is conductor string provided IZ. Is enough cement used to circulate on conductor and surface ...... .5;?!? 13. Will cement tie in surface and intermediate Or production strings 14. Will cement cover all possible productive horizons ........ 15. Will surface casing cover all fresh water zones ......... 16. Will surface csg. internal burst equal .5 psi/ft, to next string .... ~ 17. Will all casing give adequate safety in collapse and tension ...... ~1~ 18. Does BOPE have sufficient pressure rating ............... ~ Additional Requirements'