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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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Cc:Brooks, Phoebe L (OGC) Subject:FW: Trading Bay Unit G-13 (PTD 1680570) - AIO 5.028 Compliance Temperature Survey - April 2022 Date:Wednesday, May 25, 2022 9:44:20 AM Attachments:G-13 Temperature Survey Overlay Plot - 2022_04_27.pdf From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Thursday, May 19, 2022 12:13 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Trading Bay Unit G-13 (PTD 1680570) - AIO 5.028 Compliance Temperature Survey - April 2022 Mr Wallace, Per AIO 5.028 (Administrative Approval), Trading Bay Unit G-13 (PTD 1680570) requires a biennial temperature survey. The 2022 survey was completed on 4/27/2022. The survey data (see attached plot) is consistent with previous temperature surveys and confirms that all the injected fluids are being contained in the approved strata. Let me know if you have any questions or require additional information/data. Thanks Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 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 theonward 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. Well: Field:04/27/2022Hilcorp G-13 Grayling 40 50 60 70 80 90 100 110 120 130 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 Temperature (Deg. F)Depth-MD, (feet)Pressure (psia) 22 Pressure Perfs 17 3/4"13 3/8"9 5/8" 7"4 1/2"packer 18 Press 20 Press 22 Temperature 18 Temp 20 Temp Pressure-Temperature Profile 1. 2018 - 2020 - 2022 Overlay 2. Well Shut In C Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Tuesday, August 28, 2018 11:09 AM To: Wallace, Chris D (DOA) Cc: Holly Tipton Subject: G-13 Compliance Temp Survey (PTD #1680570 - AIO 5.028) 08-15-18 Attachments: G-13 Temp Survey 8-15-18 vs 8-8-16.xls; G-13 2014-06-02.pdf, G-13 swedge tool jpg Hi Chris, Well G-13 (PTD 1680570) was granted a return to injection under Administrative Approval (AIO 5.028) on September 1, 2016. As required under the approval, a biennial temperature survey was run on 8-15-18. The survey (see attached) is very, consistent with the temp survey run on 8-8-16. The 2018 survey reconfirms that the injected fluids are passing the packer and remaining below the packer after exiting the casing (ie there isn't any indication of fluid movement above the depth of the packer). This survey didn't get as deep as the previous 2016 survey, but did get close enough to the packer (within —8') to ensure containment in the approved injection strata. In multiple attempts to get deeper, both a swedge and the lower temp tool were badly damaged (see pic of swedge). Please contact me if you have any questions concerning the survey. Thank you Larry 777-8322 SCANNED AUG 3 0 2018 f-4-11> 1($ 07S -r(D Hilcorp Well: I G-13 (PTD 1680570) Field: Grayling 08/27/2020 1000 2000 3000 4000 5000 d d w— 0 6000 .0 IZ 7000 8000 9000 10000 11000 12000 60 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 70 80 90 100 110 120 130 140 150 16C 8-27-20 Pressure — Perfs 17 3/4" 13 3/8" 9 5/8" 7' 4 1/2" x packer 8-15-18 Press 8-22-16 Press 8-27-20 Temperature 8-15-18 Temp 8-22-16 Temp 1000 2000 3000 4000 � 5000 01 d) 6000 r Q 0 7000 8000 9000 10000 11000 12000 60 PTS I68o s'� o Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 70 ' 80 90 100 110 120 130 140 150 160 8-15-18 Pressure — Perfs — M 17 3/4" y 13 3/8" 9 5/8" 7" 4 1/2" packer —8-15-18 Temperature 8-8-16 Temp • • Ti) 16 $0,570 Hilcorp Alaska LLC I WeII:IG-13 I FieId:IGrayling 108/22/2016 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 Pressure-Temperature Profile 1000 1. 8-8-16 vs 8-22-16 Overlay - 2. Well Shut In 2000 _- n 3000 SCAM& G r , 4000 5000 0) Q1 6000 tlkik- IZ n-- G 7000 L 8000 1 NNW L 9000 - 10000 - - 11000 - X 111- 4IP AMMO,. Mil- 4 it NNE 12000 -- 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) 8-22-16 Pressure - Perfs —17 3/4" 13 3/8" m -9 5/8" 7" 4 1/2" packer —8-22-16 Temp —8-8-16 Temp • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, July 12, 2016 10:00 AM To: 'Larry Greenstein'; Regg,James B (DOA) Cc: Dan Marlowe;Wayne Johnson; Stan Golis;Jeff Allen Subject: RE: Possible integrity loss on Grayling - G-13 (PTD# 1680570) Larry, As discussed on the telephone, injection for up to 28 days for diagnostics and monitoring is approved. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907) 276-7542(fax),chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Friday, July 08, 2016 3:01 PM To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: Dan Marlowe; Wayne Johnson; Stan Golis; Jeff Allen Subject: Possible integrity loss on Grayling - G-13 (PTD# 1680570) %moo DEC 0 6 2016 Hi Jim, Knowing Chris is off work today, we wanted to inform you that we have shut-in the Grayling G-13 EOR well this morning due to a possible loss of mechanical integrity. The attached plot shows that after a waterflood upset back in early April,the IA on this well showed a slow, but steady increase in pressure from -200 psi up to 750 psi (-5 psi/day). We were preparing to do a bleed down to see if this pressure was a slow thermal change when this morning the IA was found at 2900 psi and the well was shut-in. We are requesting to be allowed to temporarily bring this well back online to perform some diagnostic work that would include: Wellhead servicing to eliminate the possibility of a seal or grease problem in the wellhead itself Casing and/or tubing bleed downs to verify the suspected tbg x IA communication A 12 hr shut-in temperature survey, once a stable downhole temperature profile is established,to look for a secondary casing integrity issue As we don't have an existing baseline temp survey and if all the above diagnostics seem to indicate a tbg x IA integrity problem, we'll shut the well back in to get a longer term baseline temp survey to overlay with the 12 hr shut-in survey. A temporary injection window of one month would allow all the diagnostic work to be completed. Thank you 1 . • • • C> C> CD •=. CD CD CD C> CD C> C> C) C> CD r•-• ko kr) -7 •••-) eV ..--4 CD a a ...ta :-. CD ("NJ CD 0 ii C> c eV •,...• ••••-• elJ Cri CD ...... ? 0 0 #4. I kb a% 1.11 0 K2 0 0 0 ell 4,--. • In .-I < 0 0 le, M I CO CII C AS .-• •-• ,,...:=• 1 CV .1" .." CD , -.......".k ...c................... .... ... ..107.1111.111111121 "..1"1•1111MiliMilid...... ..1Z tri CD CN :' -.... CD 0 0 CD CD 0 0 0 r-• CD CD CD 0 CD • e ell 0 VI C> VI (-4 •-k4 .-• •,..1 • • McArthur River Field SCHEMATIC Well: G-13 Last Completed: 05/23/14 Hilcorp Alaska,LLC CASING DETAIL j xo 2 SIZE(in) (ppf) GRADE ID(in) CONN TOP(ft) (ft) 17-3/4" Spr Weld Surf 602 13-3/8" 61 J-55 12.537 Butt Surf 5,115 9-5/8" 40&47 N-80&P-110 8.688 Butt Surf 11,350 7" 29 N-80 6.187 Butt 11,220 12,000 TUBING DETAIL Polycore 4-1/2" 12.75 L-80 3.680 BTC Surf 11,031 JEWELRY DETAIL No DepthfhID(in) Conn. Length Item ) 1 39' - - 0.80 Tubing Hanger 2 39.80' 3.680 BTC 4.00 4-1/2"EUE Pin x 4-1/2"BTC Box X-Over 3 10,991' 4.000 BTC X LTC 0.75 4-1/2"BTC Box x 5-1/2"LTC Pin 4 10,992' 5.000 5.75 9-5/8"Hydraulic Permanent Packer XO 3 5 10,997' 2.992 LTC X IBT 0.80 5-1/2"LTC Box x 3-1/2"IBT Pin 4 6 11,030' 2.810 1.40 3-1/2""XN"Nipple x0 5 7 11,031' 2.992 0.70 3-1/2"Wireline Re-Entry Guide Max DP 10,464ft- 10,672ft 39.5° 6 G-5 PERFORATION DETAIL liner 11,220ft MD G-5 Zone (Mp) Btm(MD) Top(TVD) (TVD) Condition Date 9,369ft TVD DIP=35° G-5 11,164' 11,247' 9,326' 9,393' Open 5/20/2014 HB+1 12 hpf HK-1 11,370' 11,400' 9,494' 9,519' Prod 10/68-9/78 HK-2 11,410' 11,500' 9,527' 9,600' HB+112hpf 10/68-9/78 Prod L Tight 5 HB+112hpf HK 3-4 11,520' 11,720' 9,617' 9,780' Prod 10/68-9/78 95/8in liner A.,°°°.... at 11,384' HB+112h f BTM:11,350ft HK-lcleaned out HK-5 11,740' 11,770' 9,797' 9,821' Prod p 10/68-9/78 with 3-5/8" bit below this point HK-2 517-14 Tagged had at 11 600fl HK-3 wd 3-5/8in mil HK-4 • HK-5 1 PBTD=11,700' TD=12,014' Updated By:JLL 06/02/14 MEMORANDUM State of Alaska Packer Depth Pretest Initial Alaska Oil and Gas Conservation Commission Well DATE: Monday, July 21, 2014 TO: Jim Regg �' ( % `F ��% �l Z W - P.I. Supervisor ( 1 / SUBJECT: Mechanical Integrity Tests IA HILCORP ALASKA LLC 2500 G-13 FROM: Johnnie Hill TRADING BAY UNIT G-13 Petroleum Inspector TD 1680570 Sre: Inspector SPT Reviewed By: 2288OA P.I. Suprv, liP-P— 0 NON-CONFIDENTIAL Comm Well Name TRADING BAY UNIT G-13 API Well Number 50-733-20127-00-00 Permit Number: 168-057-0 Insp Num: mitJWH140614092540 Rel Insp Num: Inspector Name: Johnnie Hill Inspection Date: 6/3/2014 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well G-13 Type Inj W - TVD 9152 - IA 0 2500 2500 - 2490 - 2490 TD 1680570 Type Test SPT Test psi 2288OA 0 0 0 0 0 - Interval INITAL P/F P Tubing 3100. 3100 3100 3100. 3100 , Notes: scam OCT 06 20' 14 Monday, July 21, 2014 Page 1 of I Brooks, Phoebe L (DOA) Kph IAoS70 From: Larry Greenstein [Igreenstein@hilcorp.com] Sent: Tuesday, July 15, 2014 8:06 AM To: Brooks, Phoebe L (DOA) Subject: RE: MIT_ Grayling_06-03-14 Attachments: G-13 Schematic 06-02-14.pdf Be glad to, Phoebe. Do you have the directional that translates the MD to TVD?? If the TVD is off, we did run the test pressure up above the minimum required, so the test should still be valid. I'll leave it to you to tell me if we have the wrong TVD. Larry From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.aov] Sent: Monday, July 14, 2014 2:40 PM To: Larry Greenstein Subject: RE: MIT—Grayling-06-03-14 Larry, Would you please send me the well schematic for G-13 so I could verify the packer TVD? Thank you, Phoebe Phoebe Brooks Statistical Technician 11 SCAMW Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Larry Greenstein [ma iIto: IgreensteinCa>hilcorp.com] Sent: Wednesday, June 04, 2014 1:36 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: James Young; Stan Golis; Chet Starkel; Wayne Johnson; Claude Owen; Zachary Rolph Subject: MIT—Grayling-06-03-14 Gentlepeople, Here is the official report of the successful MIT performed and witnessed on the Grayling platform on 06/03/14. Larry Ma 10,4 10,6 MY uner 11,n 9,30 DIP=? 95 ar PBTD =11,700' TD =12,014' SCHEMATIC McArthur River Field Well: G-13 Last Completed: 05/23/14 CASING DETAIL SIZE (in) JEWELRY DETAIL GRADE ID (in) CONN TOP (ft) (ftM Length (WT 1 39' - 0.80 17-3/4" - 39.80' - Spr Weld Surf 4-1/2" EUE Pin x 4-1/2" BTC Box X -Over 3 10,991' 4.000 BTC X LTC 0.75 4-1/2" BTC Box x 5-1/2" LTC Pin 602 13-3/8" 61 J-55 12.537 Butt Surf 10,997' 2.992 LTC X IBT 0.80 5-1/2" LTC Box x 3-1/2" IBT Pin 6 11,030' 5,115 9-5/8" 40 & 47 N-80 & P-110 8.688 Butt Surf HK 3-4 0.70 3-1/2" Wireline Re -Entry Guide 9,617' 9,780' HB + 112 hpf 10/68-9/78 11,350 7" 29 N-80 6.187 Butt 11,220 HK -5 11,740' 11,770' 9,797' 9,821- HB + 112 hpf 10/68-9/78 12,000 TUBING DETAIL 4-1/2" 12.75 L-80 3.680 PoIByTC re Surf 11,031 PERFORATION DETAIL Zone JEWELRY DETAIL Top (TVD) No D(efp)h ID (in) Conn. Length Item 1 39' - 0.80 Tubing Hanger 2 39.80' 3.680 BTC 4.00 4-1/2" EUE Pin x 4-1/2" BTC Box X -Over 3 10,991' 4.000 BTC X LTC 0.75 4-1/2" BTC Box x 5-1/2" LTC Pin 4 10,992' 5.000 5.75 9-5/8" Hydraulic Permanent Packer 5 10,997' 2.992 LTC X IBT 0.80 5-1/2" LTC Box x 3-1/2" IBT Pin 6 11,030' 2.810 1.40 3-1/2" "XN" Nipple 7 11,031' 2.992 HK 3-4 0.70 3-1/2" Wireline Re -Entry Guide PERFORATION DETAIL Zone Btm (MD) Top (TVD) Btm Condition Date (Mp) (TVD) G-5 11,164' 11,247' 9,326' 9,393' Open 5/20/2014 HK -1 11,370' 11,400' 9,494' 9,519' HB+112 hpf 10/68-9/78 Prod HK -2 11,410' 11,500' 9,527' 9,600' HB+112 hpf 10/68-9/78 Prod HK 3-4 11,520' 11,720' 9,617' 9,780' HB + 112 hpf 10/68-9/78 Prod HK -5 11,740' 11,770' 9,797' 9,821- HB + 112 hpf 10/68-9/78 Prod Updated By: JUL 06/02/14 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate R] Other ❑� Convert to Injector Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension[] Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspendedell 2. Operator 4. Well Class Before Work: 5. Permit to Name: Hilcorp Alaska, LLC Development E] Exploratory ❑ Stratigraphic❑ Service ❑ 168-057 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: JON 2 3 20014 Anchorage, AK 99503 50-733-20127-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 Trading Bay Unit/ G-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil Pool, Middle Kenai G Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,014 feet Plugs measured 11,700 feet true vertical 9,997 feet Junk measured N/A feet Effective Depth measured 11,994 feet Packer measured 10,992 feet true vertical 9,991 feet true vertical 9,187 feet Casing Length Size MD TVD Burst Collapse Structural 365' 26" 365' 365' Conductor 602' 17-3/4" 602' 602' Surface 5,115' 13-3/8" 5,115' 4,465' 3,090 psi 1,540 psi Intermediate 11,350' 9-5/8" 11,350' 9,445' 5,750 psi 3,090 psi Production Liner 780' 7" 12,000' 9,946' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.75 / L-80 11,031' (MD) 9,218' (TVD) 10,992' (MD) Packers and SSSV (type, measured and true vertical depth) Hyd. Perm Pkr 9,187' (TVD) SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 14 7 216 1234 80 Subsequent to operation: 0 8 6853 324 3100 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development[] Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL❑ 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: 314-270 Contact Dan Taylor Email dtayloraehilcorp.com Printed Name Title Operations Engineer Signature -e./- elft' Phone (907) 777-8319 Date 6/23/2014 Form 10-404 Revised 10/2012 �M� Submit Original Only I n Ililcorp Alaska, LLC Max DIP 10,464ft - 1Q672ft 39.5° G5 Liner 11,220ft MD 9,369ft TVD G-5 D P--35° I f� 9 5/Sin Liner Tight spot 9 5/91n1, MI at 11,384' HK -1 HK -2 HK -3 HK -4 PB1D=11,700' TD =12,014' SCHEMATIC McArthur River Field Well: G-13 Last Completed: 05/23/14 CASING DETAIL JEWELRY DETAIL Top (TVD) No D(eip)h ID (in) Conn. SIZE (in) Item GRADE ID (in) CONN TOP (ft) (ftM Tubing Hanger (p7 39.80' 3.680 BTC 4.00 4-1/2" EUE Pin x 4-1/2" BTC Box X -Over 17-3/4" - 4.000 - Spr Weld Surf 4 10,992' 5.000 5.75 9-5/8" Hydraulic Permanent Packer 5 602 13-3/8" 61 J-55 12.537 Butt Surf 2.810 1.40 3-1/2" "XN" Nipple 7 11,031' 2.992 5,115 9-5/8" 40 & 47 N-80 & P-110 8.688 Butt Surf Prod 11,350 7" 29 F N-80 6.187 Butt 11,220 12,000 TUBING DETAIL 4-1/2" 12.75 L-80 3.680 PoIByTCre Surf 11,031 PERFORATION DETAIL Zone JEWELRY DETAIL Top (TVD) No D(eip)h ID (in) Conn. Length Item 1 39' - 0.80 Tubing Hanger 2 39.80' 3.680 BTC 4.00 4-1/2" EUE Pin x 4-1/2" BTC Box X -Over 3 10,991' 4.000 BTC X LTC 0.75 4-1/2" BTC Box x 5-1/2" LTC Pin 4 10,992' 5.000 5.75 9-5/8" Hydraulic Permanent Packer 5 10,997' 2.992 LTC X IBT 0.80 5-1/2" LTC Box x 3-1/2"IBT Pin 6 11,030' 2.810 1.40 3-1/2" "XN" Nipple 7 11,031' 2.992 HK 3-4 0.70 3-1/2" Wireline Re -Entry Guide PERFORATION DETAIL Zone Btm (MD) Top (TVD) Btm Condition Date (Mp) ( G-5 11,164' ' 11,247' 9,326' 9,393' Open 5/20/2014 HK -1 11,370' 11,400' 9,494' 9,519' HB + 112 hpf 10/68-9/78 Prod HK -2 11,410' 11,500' 9,527' 9,600' HB + 112 hpf 10/68-9/78 Prod HK 3-4 11,520' 11,720' 9,617' 9,780' HB + 112 hpf 10/68-9/78 Prod HK -5 11,740' 11,770' 9,797' 9,821' HB + 112 hpf 10/68-9/78 Prod Updated By: JLL 06/02/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-13 50-733-20127-00 1 168-057 1 5/2/14 5/23/14 Daily Operations: 05/02/14 - Friday Receive verbal approval for rig workover portion of sundry @ 15:54 from AOGCC Victoria Ferguson. Prep for N/D. Install BPV, N/d flow line & valves f/wellhead. R/U landing jt t/ tree cap. R/D circulating lines. 05/03/14-Saturday PJSM. Prep wellhead & plug hanger neck. N/U xo spool, riser, mudcross, doublegate, annular, & flow nipple. R/U accumulator lines, choke & kill lines. PJSM. Finish r/u accumulator lines, run FIW line t/ pits. R/U flow line, hang curtain wall & tarp. R/U test pump hose. Function test BOPE - good. 05/04/14 - Sunday PJSM. Service rig. Run in 3 1/2" test jt, fill stack, choke manifold & standpipe manifold. Replace seals on kill line HCR function good, shell test BOPE 3000 good. Test BOPE as per Hilcorp & AOGCC regulations, witnessed by AOGCC inspector Jeff Turkington. Test BOPE 250 low, 3000 high, test Annular 250 low, 2500 high. Test with 3 1/2" & 2 7/8" tj, all good. Pull test jt & I/d. Pull TWC. Install BPV. P/U modify flow nipple. Shoot fluid level @ 2,263'. M/U landing jt. Backout I/d pins. Pull hanger free @ 100k, cont. pull t/150k. Work string making no headway. M/U E-Line rih w/2" GR t/11,380'. POOH. P/U 2" RCT, rih t/ 11,290' middle of last jt above packer, make cut. POOH & I/d. 05/05/14 - Monday Work pipe after cutting @ 11,290', making no headway. P/U & let set in tension while getting free point tools out. Receive free point tools, side entry sub & hands on boat. R/U side entry sub assembly & p/u free point tools on e-line. RIH take reading's @ 5,256', 7,072', 8,062' & 9,045' - all free. Seemed to be pushing something down hole from 8,500', take reading @ 9,818'40% free. POOH I/d tools. P/U 2" RCT & start in hole, Rih t/ 9,765', pull 15k over & cut pipe, op fell off string wt. POOH w/ e-line. R/D e-line, side entry sub, & I/d hanger. POOH laying down 3 1/2" production tubing. EOT I/d 120jts 1- GLM, 1- sssv & control line 3,629'. 05/06/14-Tuesday Cont. POOH & I/d 3 1/2" production tubing.,_ L/D total of 317 & 1-13.6 cut jt, 11 GLM, total 9,710'. Clear & clean floor & drill deck, prep tubulars for backload. Prep BHA. Start P/U BHA, m/u jars & bumper sub, overshot & xo. Unable t/tq connection on overshot. Wait on tool. Housekeeping. Cont. p/u BHA #1-Overshot w/3 1/2" grapple, xo, Bumper jar, Oil jar, (6)- 4.75" DC, Accelerator jar, xo =223.84'. P/U 2 7/8" PH-6 wk string t/2,199'. 05/07/14 - Wednesday Cont. TIH w/ BHA #1. P/u 2 7/8 PH-6 wk string t/ 9,708', up wt 94, do wt 60. Engaged fish @ 9,760', up wt 94, do wt 60, jarred on it for 2 hrs pulling up t/ 194k w/ no headway. Call out e-line. Continued jarring moved fish up hole, wt came down t/ 130k, cont pulling wt fell off t/ 112k @ 9,680'. C/O elevators, start POOH standing back wk string. Stand back collars, I/d BHA t/overshot, w/16' cut jt. Cont I/d production tubing fish t/ cut jt, 1- cut jt 16.13', 49 full jts, 4 GLM, 1- sliding sleeve, 1 cut jt 12.23', 1518', tof 11,290' wlm. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-13 50-733-20127-00 1 168-057 1 5/2/14 5/23/14 Daily Operations: 05/08/14 - Thursday Clear & clean floor. Install wear bushing. P/U BHA #1-Overshot w/3 1/2 grapple, Bumper jar, Oil jar, 6- 4.75" DC, Accelerator jar, xo =222.81'. TIH t/10,333' w/2 7/8" wk string f/derrick. Cont. TIH, p/u jts 2 7/8" PH-6 wk string t/11,220' @ liner top, rot & wk several times to get through up wt 108, do wt 64. Cont. TIH t/11,229' wash do t/ 11,280' tag up. Set down 10k, p/u 12k over, pump 3 BPM, 143 psi. Wk Pipe, p/u t/140k w/no movement or jar action, s/o t/50 & p/u t/150 w/same results. Cont. wk pipe up t/194k, circ @ 3bpm wk free. Pooh t/ 11,245' I/d single. Cont. POOH hanging up t/11,230' free, TIH t/ 11,280' tag, up wt 108, do wt 64. POOH t/ 10,776' start pulling wet. R/U circ. @ 3bpm, start getting oil back. S/d & get NPFT, line up & start pumping to production @ 3bpm, 130 psi, circ 435 BBLS, Cont. POOH. 05/09/14 - Friday Cont. POOH. Stand back collars, I/d BHA, found grapple full of scale. Clear floor, pull floor panels, n/d flow nipple, install Halls head adapter & nipple. P/U BHA #3-washover shoe, jt 5.75 wash pipe, top sub, bumper sub, oil jar, 6-4.75 Drill collars, acceleratorjar, xo= 257.05'. TIH w/ 2 7/8 work string t/11,217' up wt 110, do wt 60, rotate through liner top, cont. 11,247'. Install Halls head element. CBU Clean @ 3BPM, 200 psi, wash down t/ 11,272' scale in returns. R/U power swivel, Rot wt 94, tq off 2800, on 3200-3800, w/d t/11,299', stopped making headway, no tq or psi increase. CBU clean. 05/10/14-Saturday Pull Halls head element. POOH, stand back collars, I/d BHA, shoe no wear. P/U BHA #4-Overshot w/3 1/2 grapple, Bumper jar, Oil jar, 6- 4.75" DC, Acceleratorjar, xo =222.27'. TIH on 2 7/8 wk string t/ 11,282' up wt 108, do wt 62. TIH t/ 11,282', tag, p/u no op, come down rot fall over, take wt @ 11283' set down t/ 50k, p/u t/ 140 and jar. Set down cock jars, p/u t/145 start dragging up, drag for 25', then wt fell off t/108. Cont p/u clean, monitor hole static. POOH, stand back collars, I/d BHA retrieve in overshot - 1-cut it 15.43, seal assembly 21.45 & a cut jt 18.80. Clean & clear floor, pull floor panels, c/o flow nipple, pull wear bushing. 05/11/14-Sunday Pull wear ring, m/u 2 7/8 tj, install test plug, fill stack, manifolds & tj, Test BOPE as per Hilcorp & AOGCC regulations, witness waived by AOGCC Jim Regg on 5-9-14 @ 22:49, test BOPE 250 low, 3000 high, test Annular 250 low, 2500 high Test with 2 7/8 tj, all good. Pull tj & plug, install wear bushing, pull floor apart, install halls head flange/flow nipple assy, re- install floor. Pump fluid f/pits t/production. P/U BHA #5- packer retrieval spear, packer mill sub bushing-4 3/4 motor, xo, 2- junk baskets, xo, string magnet, bumper jar, oil jar, 6-4 3/4 DC, acc. jar, xo = 271.94'. TIH t/ 11,290'w/ 2 7/8 wk string, up wt 108, do wt 60. Install halls head element, p/u power swivel, run circ. lines f/production's waterflood, & f/ ann. t/ flow line. Start circ. w/waterflood, flow meter not reading troubleshoot. Bring flow rate up to 2780psi, rot 50rpm, tq 3-4k, wob 1-1.5k, tag mill @ 11,299', mill t/ 11,303'. 05/12/14 - Monday Fish moving downhole 10' no wt. P/U had 20k drag coming up. R/d swivel, POOH stand back wk string, I/d BHA, retrieve 6" bottom guide of packer, 3-grapple segments missing from retrieval tool. Clean & clear floor, swap out halls head f/flow nipple assy. P/U BHA #6, 8 1/2 bit, 9 5/8 scraper, bit sub, bumper jar, oil jar, 6- 4 3/4 dc, acc jar, xo= 226.09'. TIH t/ 11,217', tol, tight @ 10,738' wk through till clean. POOH t/ 3,995'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-13 50-733-20127-00 1 168-057 1 5/2/14 5/23/14 Daily Operations: 05/13/14 -Tuesday Cont. POOH, 3,995' stand back wk string, I/d BHA. P/U 7" c/o BHA # 7- 6" mill, scraper, xo, bumper jar, oil jar, 6-4 3/4 dc, xo = 215.14'. TIH t/11,292' tag, up wt 108, do wt 62. Try to wk past no go. P/u power swivel, Rot wt 82, rev. circ @ 3 BPM, 180 psi, wash & ream to 11,292', pressure up t/ 700. P/u & wk pack off free, cont wash down slow getting scale returns, packing off @ BHA if moving down too fast. Cont. wash & ream t/11,384', tq up attempt t/ wk through, set down w/o rot 15k, p/u w/10k op. Unable to make headway. (9 bbl loss f/ last 24 hr ). L/D swivel, start POOH. 05/14/14 - Wednesday Cont POOH w/ 7" c/o assy f/ 11,384'. Stand back 2 7/8 wk string, I/d BHA. Found slight wear on outer edge of mill & pieces of packer slips in mill ports. Clean & clear floor, rig maint. R/U wireline. RIH w/4.5" magnet t/ 11,340' wlm, retrieve fine metal shavings & 1" metal pcs. P/U 3" DD bailer, RIH t/ 11,408', wk sticky. POOH had markings on btm. bailer. Rih w/2.5" LIB coming back with no face markings and gouges on one side. R/d wireline. R/d floor & c/o flow nipple t/ halls head adaptor. R/u circulating lines f/waterflood & t/flow line. P/U BHA run #8, Taper mill 5.875, xo, string mill, 4 3/4 motor, xo, 2 -junk baskets, xo, string magnet, bumperjar, oil jar, (6)-4 3/4 DC, acc. jar, xo = 274.96'. TIH t/11,380', up weight 114k, down weight 60K. R/u power swivel. Break circ w/ waterflood & start washing down. 05/15/14 - Thursday Wash do t/11,384', up wt 110, do wt 62, rt wt 84, tq 3000, circ w/waterflood @ 4.5 bpm, 2775 psi. Mill on obstruction, not breaking through. P/u & consult w/ town. R/U circ lines t/check injection rate. 2800 BPD @ 2100 psi, 3000 BPD @ 2500 psi. R/D circ. lines. L/d power swivel. R/d halls head element. Pooh w/ 2-7/8 work string & BHA. Slip and cut drill line, 190FT. M/U 3-5/8" 3 bladed mill, string mill, M1V mud motor, dual circ sub- hydraulic disconnect, dual flapper, check valve, g -force jar, x/over, trip in hole w/ 2-7/8 work string to 11,363'. UP WEIGHT 82K, DOWN WEIGHT 50K. Rig up power swivel and brk circ. WASH DOWN TO 11,388'. 05/16/14 - Friday Held pre job meeting and JSA. Continue filling hole w/ FIW. Wash down f/ 11,333' to 11,363', attempt to make connection, can not brk out power swivel. Trouble shoot same, connection in derrick loose not letting fluid flow thru. Wash & ream f/ 11,363' to 11,600' with no problems. Running 0/5 WOB, pumping at 3 bpm at 524 psi w/ surface rpm at 20 rpm & approx. 300 rpm at motor w/ 2200 ft. lbs. torque on surface at beginning of reaming and 2600 ft. lbs. at end of reaming. At 11,600' hole was packing off and motor appeared to be stalling out, shut reaming ops. Circ to clear liner. Pooh thru liner slow w/ no problems or over pulls. Continue to pooh lay out BHA (3-5/8" 3 bladed junk mill, 3-5/8 smooth od string mill, M1V mud motor, dual circulation sub, Fau-ht Hydraulic disconnect, dual flapper check valve, G -force jar, x/o = 25.64 ). Rig down floor, nipple down halls head & rig up flow nipple. Rig up floor, make up Tri- point 29# JS -2 test packer & trip. in hole w/ same on 2-7/8 ph -6 workstring. SET AT 11.305' UP WEIGHT 100K DOWN WEIGHT 58K. HOLDING 2500 ON TEST. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-13 50-733-20127-00 168-057 1 5/2/14 5/23/14 Daily Operations: 05/17/14 -Saturday Finish testing the 7" x 9-5/8" csg to 2500 psi for 30 minutes on chart ( good test ) with the packer set at 11,305'. Bleed off pressure and rig down lines. Pooh w/ 10 st 2-7/8 work string. Pg-5/8 RTTS tools and storm packer and RIH w/ same and set at 180'. Pooh, test same to 600 psi., Rig down flow nipple and make brk on bop's and pick up stack and hang off same. Break connection on tbg spool and remove same. Prep head and install new 13-5/8" 3m x 11"5m tbg spool a Atest same to 2500 psi. Install riser and pick up Bop stack and set same in place and torque up connections. Clear cellar of all tools and rig up flow nipple & install floor plates. Test the break between the tbg spool & bop's to 250 low and 2500 high. Drain stack & make up test plug w/ 2-7/8 test equipment. 05/18/14 -Sunday Finish rigging up 2-7/8 test equipment. Rig up and test bops' with 2-7/8 and 4-1/2" pipe to 250 low and 3000 psi high, held each 5 minutes on chart. Test made w/ FIW. Mr. Jim Regg (AOGCC) waived the bop test witness on 5-16-2014 at 12.26 PM. Rig down test equipment. Pick up stinger, RIH attempt to make up storm valve, unable to make up same. Circ on top of storm valve to clean same, make up stinger and check tbg for pressure, tbg on vacuum, close annular, release Rtts and check for pressure, "0" open fill hole w/ 7 bbls FIW monitor well ( well static ). Pooh laying out RTTS & storm valve. Pooh laying out the 7" test packer. Make up mule shoe and trip in hole w/ 2-7/8 work string to 11,311'. Rig up lines to reverse circ. Reverse circ at 3 bpm at 180 psi displacing well with clean FIW. l` 4 1 � 05/19/14 - Monday Continue to reverse circ displacing well with clean FIW. Rig down circ lines and pooh lay out mule shoe. Cleaning rig while waiting on TCP & E -line Crew to arrive. Laying out TCP tools & BHA. Held pre job meeting. Picking up 4-5/8 T -CP guns & assembly. Trip in hole at 30 seconds p/ std. Drifting pipe depth at rpt time 7,793'. 05/20/14 -Tuesday Continue TIH w/ TCP assembly to 11,304' ( drifting pipe ). Rig up E -line in derrick, test lubricator to 1000 psi. RIH w/ 1-11/16 gamma ray, make correlation log, spot guns on depth placing top shot at 11,164' and btm shot at 11,247', relog and verify guns on depth. Pooh and rig down E -line rig up and drop bar, fire the 4-5/8" 5 spf guns 83 feet of shots. ( had good indication guns fired ). Monitor well, had no pressure build up, open well fill with 1 bbl FIW, reverse circ two tbg volumes circ out gun gas, shut down pump ( well static ). Open well, monitor well, hole taking 4 bph rig down circ lines. Pooh laying down 2-7/8 work string. Pooh laying out TCP guns ( all shots fired ). Clear floor of tools and cleaning same. Rigging up floor and offloading production tbg. 05/21/14 - Wednesday Held prejob meeting. Make up mule shoe, 1 jt 3.5" 9.3# N-80 tbg, x/o, Tri -point 9-5/8" perm pkr assembly. TIH picking up 4.5" N-80 poly core buttress tbg, drifting same. Depth at rpt time at 10,500 ft. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-13 50-733-20127-00 1 168-057 1 5/2/14 5/23/14 Daily Operations: 05/22/14 - Thursday Made up hanger & landing jt. Landed same, ran in pins. Rigged up slick line, test lubricator to 1000 psi, made a 2.80 ga run. Set down on nipple at 11,021' SLM. POOH. Rigged up circ lines, circ 600 bbls of FIW treated w/ Baker Petrolite CRW-0132 corrosion inhibitor packer fluid mixed at 2% pumping at 2 bpm 50 psi. Rig up and drop the 1-3/8 RHCP bar and let fall. Pressure up on tbg to 3500 psi and set the Tri - point Stimtop hydraulic perm packer at 10,991' MD. Btm of mule shoe at 11,032'. Held pressure for 10 minutes, bleed off same. Rig up line to csg valve and test the 9-5/8 x 4-1/2 tbg annulus, packer top and hanger to 2500 psi for 30 minutes on chart ( good test ). Slick line RIH and retrieve bar and 2.812 RHCP plug. Rig down tongs & equipment. Set back pressure valve. Rig down floor. Nipple down BOP'S and hang under floor. Nipple down risers. 05/23/14 - Friday Finish nippling up tree, test void to 5k. Pull BPV & install two way check, shell tested tree to 5k on chart for 30 minutes. Pulled two way check, made up tree cap. Moved pollution pan off rig floor. Installed floor plates, removed curtains off front side. Laid down v -door. Moved pipe racks & catwalk. Rigged down hard lines from choke manifold & gas buster & rigged down flow line. Pumped out pits. R/d stairs, form substructure to main deck, blow down & rig down suction lines. Rigging down panic line. Rigging dog house and set on deck, removing hand rails, loosen front clamps on skid, rig down back curtain, rigging down lines. t - 333 vest Seventh Avenue GOV'E1.NCP. S1-:AN E):1RNF.I-l. Anchorage, Alaska 99501-3572 NAc n on. 27c 1d�3 %OM MAY 1 6 2014 Dan Taylor Operations Engineer Hilcorp Alaska, LLC V J 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay Unit G-13 Sundry Number: 314-270 Dear Mr. Taylor: 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 // Daniel T. eamount, Jr. r4Commissioner DATED this day of May, 2014. Encl. M111J RECEIVED ' 4 STATE OF ALASKA APR g 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION s 6C/� APPLICATION FOR SUNDRY APPROVALS ®(� 20 AAC 25280 1.Type of Request: Abandon❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program❑ Suspend❑ Plug Perforations El Perforate 0 Pull Tubing[] Time Extension❑ Operations Shutdown 1:1 Re-enter Susp.Well❑ Stimulate❑ Alter Casing 0 Other. Conversion?Service 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0. 168-057 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic CI Service ❑ 6.API Number Anchorage,AK 99503 50-733-20127-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? /cm- Op aag A, Will planned perforations require a spacing exception? Yes ❑ No I I / Trading Bay Unit/G-13 t 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil Pool • 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): 12,014 9,997 11,994 9,991' 11,700 N/A Casing Length Size MD TVD Burst Collapse Structural 365' 26" 365' 365' Conductor 602' 17-3/4" 602' 602' Surface 5,115' 13-3/8" 5,115' 4,465' 3,090 psi 1,540 psi Intermediate 11,350' 9-5/8" 11,350' 9,445' 5,750 psi 3,090 psi Production Liner 780' 7" 12,000' 9,946' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11-370'-11,660' 9,462'-9,700' 3-1/2" 9.2#/N-80 11,361 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Perm Packer&Otis Ball Valve 11,307'(MD)9,442'(TVD)&293'(MD)293'(TVD) 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for 15.Well Status after proposed work: 5/5/2014 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval j' Wo 41410 Date: �5•Z•/�( WINJ El . GINJ El WAG ❑ Abandoned ❑ Commission Repres tative: g-6,1-6,1.4f s4 a ri'ltislh GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtavlorPhilcorp.com Printed Name Dan Ta I. Title Operations Engineer Signature / Phone (907)777-8319 Date 4/28/2014 �r" COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: AtT vtl Plug Integrity El BOP Test 13 .. Mechanical Integrity Test Location Clearance El Other: Q0r1 I/v acc O rc�o�,n per, c.,e LJ I11,. AK) Dog 4- 30o0 psi $e f s.�. Spacing Exception --.uired? Yes ❑ No Subsequent Form Required: I O 40 / ) JO go APPROVED BY �j Approved by. / COMMISSIONER THE COMMISSION Date: . -7/4f ?/(a ;•-•,,:;/�y� Submit Form and Form 10-403(Revised 10/2012) Approved i t�o�j7 IINIIALth rpt Om tfle date of arOval. Attachments in Du licatet RBD MS �IAY 13 2011 '` Well:Well PrognosisG-13 Hilcoru Alaska,LL Date:04/28/2014 Well Name: G-13 API Number: 50-733-20261-00 Current Status: Producer Leg: 4 Estimated Start Date: May 5,2014 Rig: NA Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-83.32 Permit to Drill Number: 168-057 First Call Engineer: Dan Taylor (907)777-8319(0) (907)947-8051 (M) Second Call Engineer: James Young (907)777-8421 (0) AFE Number: Current Bottom Hole Pressure: 3,810 psi @ 9,450ft TVD/11,320ft MD 0.40 psi/ft at mid-perf, Survey 2009 Maximum Expected BHP: 3,880 psi @ 9,450ft TVD/11,320ft MD 0.40 psi/ft at mid-pert, Survey 2009 Max.Allowable Surface 1,899 psi MBHP-2/3*TVD*0.1 psi/ft+ 1/3* Pressure: TVD*0.435psi/ft Brief Description Grayling G-13 is an oil producing Hemlock well with a gas lift completion. G-13 was drilled in 1968, hydraulically frac-ed in 1975, and acidized in 1991. It is currently producing a+/-95%water cut at+/-20bopd.The west feature of the field is lacking in sufficient water flood support. G-13 will be placed on injection to provide water flood support. This application for Sundry approval outlines the work over to pull the current gas lift completion, perforate new zones and re-perforate existing open zones, and run back in hole with an injector completion. Please see the below table of wells within 1/4 mile radius of proposed completion. Permit Number Well Number Current Stab -2onat Isolation(method) 168-057 G-13 1-OIL(proposed) Top of cement(estimated)at 6,080ft(>5,000ft above 9-5/8in shoe and G-zone), 7in cemented across Hemlock 200-038 G-28RD 1-OIL 6/2/00 USIT log,good cement to—9,150ft in 7in liner(2,000ft above top G-zone) 192-052 G-29RD 1-OIL 7/8/91 CBL,good cement to-10,700ft in 7in liner (1,000ft above top G-zone) Procedure: 1. Bleed off well. 2. Rig up slick line. 3. Run in hole and shift`XA' sliding sleeve at 11,273ft(if possible) noting fluid level. 4. Circulate down IA+/-134bbls of filtered inlet water to kill. a. Shoot and record fluid level. 5. Set back pressure valve. 6. Nipple down tree/nipple up BOP. 7. Perform BOP Test. a. If back pressure valve will not set with tree on refer to attached rolling test procedure. 8. Pull hanger and lay down. 9. Pull out of hole laying down production tubing (dry string wt, 104klbs). 10. Pick up packer pulling tool. a. Burn over and latch packer. b. Work over fluid will be filtered inlet water. 11. Circulate bottoms up and pull out of hole. a. Close bag and spot lost circulation pill if needed. 12. Pick up 9-5/8in clean out assembly. a. Trip in hole to+/-11,220ft cleaning out 9-5/8in casing. 13. Circulate bottoms up and pull out of hole. 14. Pick up 7in clean out assembly. a. Trip in hole to+/-11,700ft cleaning out 7in casing. 15. Circulate bottoms up and pull out of hole. 16. Pick up 7in test packer. a. Trip in hole to+/-11,300ft and set. b. Test casing, hold,and chart for 30min. 2 5-04D p) l e.s 17. Pull out of hole to+/-6,000ft laying down work string. • Well Prognosis Well: G-13 IIilcora Alaska,LL' Date:04/28/2014 18. Pick up storm packer. —� ZS-6Z • 4-e 5F a. Trip in hole to+/-100ft,set, and test storm packer. J° 19. Change out well head and test. .—j Jaw+401 E4r,,,Q 20. Pull storm packer and lay down. 21. Pull 7in packer assembly and lay down work string. 22. Pick up tubing conveyed perforating assembly spacing out shots over the following intervals to re-perforate. Zone Top Shot(MD,ft) Bottom Shot(MD,ft) Total Ftg(MD,ft) Current/New GZN-5 11,164 11,247 83 New HK-1 11,370 11,400 30 Current HK-1 11,373 11,388 15 New HK-2 11,410 11,500 90 Current HK-2 11,419 11,427 8 New HK-2 11,445 11,470 25 New HK-2 11,489 11,495 6 New HK-3,4 11,520 11,720 200 Current HK-3 11,530 11,555 25 New HK-3 11,563 11,575 12 New HK-3 11,611 11,623 12 New HK-4 11,663 11,700 37 New HK-5 11,740 11,770 30 Rugged 23. Pick up mule shoe, nipple, 7in 29#completi n packer and 4-1/2in lined tubing and trip in hole. 24. Set completion packer at+/-11,270ft. 25. Land hanger and test. TS f- ]'4COs' Cao 26. Turn well over to production. •1 1,41:4-11.4s5 Mt—r— t o s - Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current Well Head 4. Proposed Well Head 5. BOP Stack 6. Rolling Test Procedure McArthur River Field,TBU SCHEMATIC Well: G-13 Hilcorp Alaska,LLC As Completed: 12/19/1984 CASING DETAIL i I SIZE WT GRADE CONN TOP BTM. 17-3/4" Spiral Weld Surf 602' 1 • 2 13-3/8" 61 J-55 Surf 5115' N. 9-5/8" 40&47 N-80&P-110 Surf 11350' 7" 29 N-80 11220' 12000' TUBING DETAIL 3-1/2" 9.2 N-80 JEWELRY DETAIL No Depth Item 1 39' Tubing Hanger II2 292.72' Otis Ball Valve 3 2367.84' Camco Gas Lift Mandrel 4 4098.94' Camco Gas Lift Mandrel illi5 5256.37' Camco Gas Lift Mandrel III6 6060.22' Camco Gas Lift Mandrel 7 6547.18' Camco Gas Lift Mandrel 3-17 8 7072.28' Camco Gas Lift Mandrel 9 7565.84' Camco Gas Lift Mandrel 10 8062.65' Camco Gas Lift Mandrel 11 11 8557.67' Camco Gas Lift Mandrel 12 9045.22' Camco Gas Lift Mandrel 13 9536.66' Camco Gas Lift Mandrel 14 10054.70' Camco Gas Lift Mandrel IIII15 10553.26' Camco Gas Lift Mandrel 1 16 10924.43' Camco Gas Lift Mandrel t 17 11236.91' Camco Gas Lift Mandrel 111 18 11272.90' Otis"XA"Sleeve . 19 11306.01' Baker Locator Baker Perm.Packer with Seal 20 11306.94' Assembly 18 21 11357.30' 3-1/2"Buttress Collar 19 22 11358.00' Otis"Q"Nipple 20 23 11358.92' 3-1/2"Buttress Collar 21 24 11,359.62' Otis"XO"Sleeve L 22 23 25 11361.10' Bottom of Mule Shoe 24 lip PERFORATION DETAIL 251 Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Condition Date HB+1 12 hpf 10/06/1968- HK-1 11,370' 11,400' 9,494' 9,519' Prod 9/30/1978 —HK-1 HK-2 11,410' 11,500' 9,527' 9,600' H8+112hpf 10/06/1968- — Prod 9/30/1978 HB+1 12 hpf 10/06/1968- -HK-2 HK 3-4 11,520' 11,720' 9,617' 9,780' Prod 9/30/1978 HK-3 HK-5 11,740' 11,770' 9,797' 9,821' HB+1 12 hpf 10/06/1968- Prod 9/30/1978 —HK-4 H K-5 McArthur River Field,TBU r Proposed Well: G-13 Hikora Alaska.1.1.0 CASING DETAIL i l SIZE 1 GRADE ID CONN TOP BTM. 1 17-3/4" Spiral Weld Surf 602' 13-3/8" 61 1-55 Buttress Surf 5115' 9-5/8" 40&47 N-80&P-110 Buttress Surf 11350' 7" 29 N-80 Buttress 11220' 12000' TUBING DETAIL 4-1/2" 9.2 N-80 3.5" 8RNO Surf 11270 JEWELRY DETAIL No Depth(ft) Item 1 39 Tubing Hanger L. a 2 11,246 TriPoint Packer XO 4-1/2in X 3-1/5in LTC Box 3 11,259 X EUE Pin 4 11,260 Otis"XN"Nipple 5 11,270 Mule Shoe PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Condition Date G-5 ±11,164' ±11,247' ±9,326' ±9,393' Future HK-1 11,370' 11,400' 9,494' 9,519' HB+1 12 hpf 10/06/1968- Prod 9/30/1978 HK-1 ±11,373' ±11,388' ±9,497' ±9,509' Future HK-2 11,410' 11,500' 9,527' 9,600' HB+112 hpf 10/06/1968- Prod 9/30/1978 HK-2 ±11,419' ±11,427' ±9,534' ±9,541' Future HK-2 ±11,445' ±11,470' ±9,555' ±9,576' Futur' HK-2 ±11,489' ±11,495' ±9,591' ±9,596' HK 3-4 11,520' 11,720' 9,617' 9 780 HB+1 12 hpf 10/06/1968- Prod 9/30/1978 HK-3 ±11,530' ±11,555' ±9,625' ±9,645' . HK-3 ±11,563' ±11,575' ±9,652' ±9,662' Futur. HK-3 ±11,611' ±11,623' ±9,691' ±9,701' Future HK-4 ±11,663' ±11,700' ±9,734' ±9,776' Future HK-5 11,740' 11,770' 9,797' 9,821' HB+1 12 hpf 10/06/1968- I Prod 9/30/1978 2 L 3 4N G-5 AHK-1 ®H K-2 =HK-3 =HK-4 HK-5 L N. . . „ II Grayling Platform G-13 Current 04/21/2014 Hiknrp Alar,ka.IAA, Grayling Tubing hanger,CIW-DCB- G-13 FBB, 11 X 3 1/2 tbg,w/3"type 13 3/8 X 9 5/8 X 3 1/2 H BPV profile, 1/8"npt control line port,6%neck BHTA,CIW,3 1/8 5M FE, external knockup acme thread type wwwoswr Li lit 1111111111116 firmaiiiimo Tree assy,Block,CIW-F, 000.4..wr /" 3 1/8 5M single master, "` wing,and swab, EE trim,6'%< ®.14 h extended neck pocket,1-1/z ' 00 11 0 ! !,I '6 1 npt control line exit �` rte: Void test bad,will not �••••• pressure up Packed off with plastic injection to 5000psi 1111 ill 3/26/09 ------______-. 65 ' . 4 Tubing Head,CIW-DCB, 1#1 in 13 5/8 3M X 11 5M,w/2 Valve,CIW-F,2 1/16 5M FE, 2 1/16 5M SSO,X-bottom 01 k _a', = ( , HWO,AA trim n prep w 9 5/8 R seal installedI p � ((D���� I I-:j IA ,- al Void test bad,will not 2. ~19 .1... pressure up . Packed off with plastic Casing Head,Shaffer-KD, Br injection to 3000psi r 13 5/8 3M X 13 3/8 SOW,w/ III _ III 3/26/09 2- 2" LPO,casing hung with = k 9 5/8 Shaffer SD slips and •.J • primary plates 1._: Rockwell Ball Valve,2"LP or or t , , II Grayling Platform G-13 Proposed 04/21/2014 Hilrrrrp,Alaa,ka.1.1A, Grayling Tubing hanger,SME-CL,11 X G-13 41/2 EUE lift and 4%TC-2 13 3/8 X 9 5/8 X 41/2 susp,w/4"Type H BPV profile,2-3/8 CCL,6'%< extended neck,17-4PH stainless steel BHTA,Bowen,4 1/16 5M X 7"-5 SA Bowen Union Full Stainless Steel III la ler at nr u Valve,Swab,WKM-M, 4 1/16 5M FE,HWO,FF trim lt'', _ 1111 o �' Valve,Wing,WKM-M, 1e1 di,., 4 1/16 5M FE,w/15"Safeco \ _ operator,FF trim . O`' Full Stainless Steel 0 Valve,Master,WKM-M, isi=hi HI 41/16 5M FE,HWO,FF trim 'To CoAdapter,Seaboard,11 5M FE III — III — X41/165M,w/6'/,pocket, 2-'/CCL exits,Full Stainless Tubing head,S-8,13 5/8 3M Hi.—. ,_ Steel x 11 5M,w/2-2 1/16 5M —i r • ', e- , SSO,w/BG bottom EU.) w/2 2 1/16 5M WKM-M CI-- �L ^ 110 valves , - 1.‘*11 1= -1110.40 •-1-- 4-4:-..' 1 17kr.- - 4 t E 51 1 Pee5 DPSO,13 5/8 3M x ;= 13 5/8 3M w/3-9 5/8 P seals Casing Head,Shaffer-KD, 135/83MX133/8SOW,w/ 111 . lii 2- 2"LPO,casing hung with _ wA f�) 9 5/8 Shaffer SD slips and i01 111 ! i 1-1•=! primary plates401 0; ; ` I I 45. 1 Grayling Platform BOP Stack Moncla 04/24/2014 Ni4vup;%laska.l.iA Grayling Platform 2014 Workovers BOP Drawing Moncla III III III Milli • rir III rir lir rir rir rir rir . 3.75' . r. n: rir rir III III Iii rir ririi_rii III 4.67' EA �!�'+ _ = 2 7/8-5 variables �lC+* Blinds rir rir rir rir rir 2.00' Kill Side rir rir rir rir rir Choke side 3 1/8 5M w/HCR , + , •46111V, 3 1/8 5M w/HCR rii iir rir rir nr 1.00'to 2.00' III,i„i,,i, III Drill deck 14.20' Riser 13 5/8 5M FE X 13 5/8 5M FE rir rir rir rir rir rir rir rir rir Spacer spool 3.00' 13 5/8 5M FE X 13 5/8 5M FE III rir rir rir rir III Milli!! rir 2.83' Spacer spool 13 5/8 5M FE X 11 5M FE rii rir rir rir rir . . .. II Moncla 301 BOP Test Procedure Hilcorp AIa,I a,LLCAttachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: 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 301 BOP Test Procedure Hilcory)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. v, a) Co c E - -60 �v oo o `^ LL1.0 IA c U LL N ri M O E 7M MN i+pM N c CO J J U = J C C O @ Q. Y 0 0 cu c o Id) u E v U O u u Co j O 'd N N 2 N N V N 2 N EO tn LF, M 42 Y N 3 ++ 6i O al N1- HN m3N .t i . 4\t\.. ! ' Ill'°_Lol" LI 3§ 0 -• •-a• 01 Q - io \:7; O i M , ' .,, t/ Q Y • II ! ll. Ai 14/4/1 / Pm p • c Y it-.• p a J O Y V 10 0900( 6 I m Y C7 / o Y % \` �/A o Y o Y 6 o ce4 4 Y r O1 i,4 • • A- RD e O1s'0 A-15/2 K-13RD2 o 94'' 6° I K-O9A 5s ° 1 K-22 Op4O 960° �. .1 / 966° ,9,50 ry 9g6p0 Th . f) ,, j .0„..---0, K-,zRDz IK-15Bz' le 8 8 .1 `\ ic-isRoI -9y5o -9s9p '4"y�a-0BRD \ K-012160, ° K-O2B -9aso A -0490 G4 g K-7 i -n35o • K-03RD ,. I K-11 A MM-30 �_-.\ B��s�e A. \ K- 7B G-296 9�p0�-77 K•U]RD I. @1 K-02R\ _� ) "'bbb G29RD .5 /l 7 A, L o K-4 - G-19 f.� iK-211 ,\ �� o19 'e AG-28RD °y a $ I T M M-27 A Q27 45 zo `7 A (��• 1/ A °° ,( 9 •M-25 •• % �� „,.... ..,„0,-25 ----, ,K 24 G,]RD \ G l ♦. iii • oils,�—`Q] c D O6B EA13.4) Gd4 .9M1°0 •A ) -18ga Li 4430 - fG-140RD ° G-22p G'--T4 G D C1.3RD2 OI BRD ' a -• • • M q. ,B '� \. ��I egg R D-40RD D-42 D.28 / f-2 \ e �*• . • G28F�pC.'p]Rp GD▪ r. '• e-`J//J' o�D-11 0.ORD2 2 0 �G12RD3 e4 .$, m 7 0.17 D-0, G-11/DPN • 4 / e $ y D-43R➢ 0.2] D3,RD D-21319D (�� / j/ j 1 , '..•oS A , .0,5 D-07V //( / / R D-03RD2 d / // —D--29RD / I D-32A s ///// I � � , G15RD2 0.05R 02AR D-02C F // e ••• 0.•y J D-24A 8 °a • O-36A I �` D-25RD 8 ' o \\\\ \\, \• D•09RD •.�••M 8 e o .,::', `\ No L`12RD D-09RD e'o D-08RD — C D\.:C_____.)81)3 8 . , . N 88 o e°s 8 0--1D HILCORP ALASKA,LLC eo I 1• MCAKRUEUFIELD HEMLOCK STRUCTURE MAP i.•"2, / / / oya� ST °9 ° FEET POSTED WEll.DATA DL o '" e° 8 o .SWAN. wHr Schwartz, Guy L (DOA) From: Ferguson,Victoria L(DOA) Sent: Friday, May 02, 2014 3:54 PM To: Daniel Taylor Cc: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA); Foerster, Catherine P(DOA); Roby, David S (DOA) Subject RE:G-13 RWO and convert to INJ (PTD 168-057) Daniel, This sundry was received at the AOGCC on Monday,4/28/14 with a commencement date of Monday, 5/5/14 allowing 1 week for review and approval in our office. You then persistently called, emailed numerous times and different people today, 5/2/14, Friday for approval three days early on 5/2/14, even after being informed that the sundry would be reviewed on Monday, 5/5/14 when the PE and Geologist returned to the office. While you were successful in that we will grant verbal approval for the RWO portion of the sundry, this business conduct is unacceptable.The conversion to WI has not been approved. Victoria Ferguson Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonCa alaska.gov 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 Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov From: Daniel Taylor [mailto:dtaylor@hilcorp.com] Sent: Friday, May 02, 2014 8:54 AM To: Ferguson,Victoria L(DOA) Cc: Bettis, Patricia K(DOA); Schwartz, Guy L(DOA) Subject: RE: G-13 RWO and convert to INJ (PTD 168-057) Victoria, Good morning. I have been speaking with Guy on the Sundry application for G-13 and I understand that he is out today. The G-13 is a conversion from a producer to an injection well and requires an AOR. The application was not submitted with a spider map. There were three iterations of the AOR map that were submitted. The final map shows the location of the effected wells within a 1/4mile radius. Mr.Schwartz brought up the G-15 well bore as being within that radius and needs to be included within the review. After reviewing the G-15 history(please see below) it was found to have casing integrity. Please let me know where we stand on the application and what if any additional information you need from us. Thank you so much. 1 . Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Daniel Taylor Sent:Thursday, May 01, 2014 3:54 PM To: 'Schwartz, Guy L(DOA)'; Bettis, Patricia K(DOA) Subject: RE: G-13 RWO and convert to IN) (PTD 168-057) Patricia, I spoke with Mr.Schwartz earlier and he mentioned that he will be out tomorrow. Guy impressed upon me the importance of presenting a thorough AOR on each injector. In my last e-mail below I summarize the last well in question,G-15RD. I will be back in Anchorage tomorrow and look forward to speaking with you .Thank you. Regards, Daniel Taylor Operations Engineer From: Daniel Taylor Sent:5/1/2014 11:50 AM To: 'Schwartz, Guy L(DOA)' Cc: Bettis, Patricia K (DOA) Subject: RE:G-13 RWO and convert to INJ (PTD 168-057) Guy, Thank you Guy for the explanation. I have reviewed the G-15RD well file as well. Please see the attached schematic of the current completion on G-15RD. A 7-5/8in tie back liner was run from 10,525ft to surface. Estimated TOC is at 7,445ft based on temperature log following the 7-5/8in cement job. The historical casing and tubing pressures over the last year are also attached. We show to have casing integrity throughout the well bore and no communication beyond the IA. Thank you sir. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, May 01, 2014 12:09 PM To: Daniel Taylor Cc: Bettis, Patricia K(DOA) Subject: RE: G-13 RWO and convert to INJ (PTD 168-057) 2 • Daniel, I looked closer ... the well I was referring to was G-15RD.The map scale was pretty small so I misread the wellname. It does appear to pass through the 1/4mile radius looking from above. You must list(and document zonal isolation )of all wells in the'A radius...even if the wellbore does not pass through in the injection zone. This is done to be sure all wells are reviewed in the AOR. This includes old Plug back sections,abandoned wells etc.... Please review the AOR document and please feel free to ask any questions you might have. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz©alaska.gov). From: Daniel Taylor [mailto:dtaylor@ hilcorp.com] Sent: Wednesday,April 30, 2014 1:13 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: G-13 RWO and convert to INJ (PTD 168-057) Guy, After speaking with the geologist he mentioned that you normally like to see an AOR map in a standard format we have provided in the past. Please see the attached map in the'standard format'. This map incorporates the active wells in the area. I believe the well you are referring to is G-19A(G-16 is not present within the'A mile radius).This is a well in the planning stage and is not currently present in the field. The original G-19 is a shut in injector. Top of cement was found at 8,786ft. Please see the attached screenshots of the SLB 1998 USIT log. I will make sure to limit the confusion on upcoming wells by submitting the standard AOR map provided by our reservoir geologist that has the current completions and an outline of the distances between wells. Thank you sir. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 3 • From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, April 30, 2014 8:18 AM To: Daniel Taylor Cc: Bettis, Patricia K(DOA) Subject: RE: G-13 RWO and convert to IN) (PTD 168-057) Can you redraw the red circle to represent a 1/4 radius? It appears to be closer to a 800 ft radius. Should be centered over the well too. I see G-16RD passes through the 1/4 mile radius zone. I assume the wellbore passes above the injection zone .. can you verify this and confirm the cement status. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Daniel Taylor [mailto:dtavlor@hilcorp.com] Sent:Tuesday, April 29, 2014 5:58 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: G-13 RWO and convert to IN) (PTD 168-057) Guy, Please see the attached map of the MRF. G-13 is located in the NW section of the map and is identified by a Red circle. Thank you for your help. Regards, Dan Taylor Operations Engineer Hileorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Tuesday, April 29, 2014 3:40 PM 4 . To: Daniel Taylor Cc: Bettis, Patricia K(DOA) Subject: G-13 RWO and convert to IN) (PTD 168-057) Dan, I will need a spider map showing the X mile radius of the affected wells in the area for the AOR. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). 5 U, a 1 fO c �n u O O N LLl0 Lrl c E u ti ^ fY1 c `"' m 0 en v o 6. C7 co Mm +. 0� tU in LI'0 r, N C J V J 13 0 fp C C J 0 C d 0 '2,) ,F, 0 y 0 0 a C o a� u Ui o 7'1t' U N J OL -0 to to = N N gN � .. -0 E 4,, .•C 1 in 42.5F° o ''y� 5,' oat° 1 th v, , M- , CO , g_ W N I 1 gL< E2 ! ii !idiij 8 "r, 0 \7- 1 Nk q . 11\\\. Y 1 I Alliii0. 1, ',; b e t 2 Y / C9 r �ii9000,, r, 6 , cv Y 6 0 , 1 ccY 0 i 04caso ‘-, I 4 ARD. g oA 1i2 oK-13RD2 ,° ,g f., Lp . ;KO9A ,,i K-22°,00 9000 • K-12RD2 ,,, ' 0 pi I43 / �V 9�0 ye e K-1.1RDo I1ss5ossao s,J�-06RD 1(.01 09a P K.-O2 .9450 A \ 9900 K-1 3�.0 \. K9-44.:,,f• ` KI.SRD • K-03RD M-30 $ 44 .:,17� c-0 -0C-D2RD, _� -/ K-04RD j—.•,,,,.,‘" a44 G-29RD _ La / . • .�+, /. 14 S" G-26 RD Ai M-27 '--1�2 D ) W23 K-24RD2 . (ii.,.: G.1 \ m v • G-05RD » `a II ® G-01 RD 8 G2] ()� n M-25 G-17RD o, \\1 4R ��/,,'' •G,, 1 G.0k•i,6g / (II /^\ •-•12p 1I?* GIRD,\`� ' l ' I/1/ f I / 1 Gd0 • G-16 1 ' 111' \\ % �, 4-30 arca*(FA d • e G-14ARD / G-11 G,,yy��D -v3RD2 II 0}06RD G� _ N G 22, ^ DdORD® D-28 D<2 f1 D }. -- •o D-28A • • G 26l G.:RD / -\ • •DO]RD2 1 �/ 0 4�D-11 D-30 2 ,oG-12RD3 D 47 0-01 G-36DPN A o D-43Rp / D-27 d-31R0 D-26RD Pyo /� • o D-03RD2 s D-29RD i `//// /% D- --�D-26 Gil) D•1 /j/; / , .- 'i D-15RD2 D-05R j ( l /Q / D-02AR D-O2C / ! V � �� �' '� O45 ••• ��� - �D A I �/ ' /I/j�8'ae a a�/ 177.fr'/711 //' \ A D-• .• Lll ol 1 / / /:'l'y l,/i/i irg/. // . g /17 ice \ \\•, \ ,, ..$ � 4.12RD'•: . D-06RD Q t ^Q J j $ \$ ����\ 'fib � •///'� /(///� J \ \\\1 D-06RD t'.D-:„......!...7....) ':4/' ' ( ` � \ \ //// 1/7 / Q 1 ./ ` D-1 RD // S 1 f A■ FpLCORP ALASKA,LLC \ Q `�1 \I\ � / / I ',tilt t /�' MOARDIDRRNERFIELD M /:,,,q, �`t. `` ! { /'{//� � KELLOCN�>STRUCTURE MAV i\ \li.,'1.;,.\\\\\\ \fit /�, /44. . # / ........ �. ,,01,111 i,4 �' & ¢� ! / ? ( �j�// /� /I//i ° .w �R•oM Bettis, Patricia K (DOA) From: Daniel Taylor[dtaylor@hilcorp.com] Sent: Tuesday, April 29, 2014 5:58 PM To: Schwartz, Guy L (DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: G-13 RWO and convert to INJ (PTD 168-057) Attachments: MRF Map.pdf Guy, Please see the attached map of the MRF. G-13 is located in the NW section of the map and is identified by a Red circle. Thank you for your help. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartzCa alaska.gov] Sent: Tuesday, April 29, 2014 3:40 PM To: Daniel Taylor Cc: Bettis, Patricia K (DOA) Subject: G-13 RWO and convert to INJ (PTD 168-057) Dan, I will need a spider map showing the 1/4 mile radius of the affected wells in the area for the AOR. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.aov). 1 ((l) tì f< II\ 17 rE '\\ II /l.1\\11 ¡r (~ U ULJ U Lb 17\- \ þ' ~ I ¡ L lWú" ,-- r - ~~\ ~tr: '-'1 il\ 'i it\- ínJ ¡ j/ If' \ tr'\-:: l/i\,\\:"/", IL'\!' III.':\\!{ If\' Lrü L6 LFu æJ U\i LFJ / FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION May 4, 2004 333 W, 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verifications Well G-03RD2, PTD 183-010 Well G-04RD, PTD 181-183 Well G-13, PTD 168-057 Dear Mr. Johnson: On April 23, 2004, AOGCC Petroleum Inspector Chuck Scheve witnessed 3 "no flow tests" on Unocal's McArthur River Field, Trading Bay Unit, Grayling Platform: Well G- 03RD2, Well G-04RD, and Well G-13. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy after being shut in and monitored for several hours. There was no flow of gas or liquid to surface during the tests. Based on the results of these no-flow tests, the subsurface safety valves may be removed from service in Wells G-03RD2, G-04RD, and G-13. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, ~\ '"T") r:-J \-.--lêllvt<J t5 -. ~<& c James B. Regg 7 ( Petroleum Inspection Supervisor cc: Bob Fleckenstein ~ lrul IE' íí ~[. . ~rE (&\ n !E\ ~ íV( Æ:\ @ L.nJ U L::::J LW If lfU Lblfù æJ l}~ LiU I ; I ¡ í / AltASIi& OIL AND GAS I CONSERVATION COMMISSION / April 26, 2004 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal 260 Caviar Street Kenai, Alaska 99611 RE: No-Flow Verifications Well G-03RD2, PTD 183-0 I 0 Well G-04RD, PTD 181-183 Well G-13, PTD 168-057 Dear Mr. Johnson: On April 23, 2004, AOGCC Petroleum Inspector Chuck Scheve witnessed 3 "no flow tests" on Unocal's McArthur River Field, Trading Bay Unit, Grayling Platform: Well G- 03RD2, Well G-04RD, and Well G-13. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy after being shut in and monitored for several hours. There was no flow of gas or liquid to surface during the tests. Based on the results of these no-flow tests, the subsurface safety valves may be removed from service in Wells G-O3RD2, G-O4RD, and G-13. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, ~ n~~d Jame~. R~g~ "17 Petroleum Inspection Supervisor cc: Bob Fleckenstein MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . ~eqq tlã,,/iYr P. I. Supervisor ( DATE: April 23, 2004 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: No Flow Trading Bay Unit G-03 RD2 183-01 0 G-04RD 181-183 G-13 168-057 Friday. April 23. 2004: I traveled to Unocal's Grayling Platform and witnessed no-flow tests on wells G-O3 RD2, G-04RD and G-13. I arrived on location and found all three wells bled off and opened to atmosphere with no flow of gas or fluid evident. All three wells were shut in and observed for several hours with no pressure build up observed. I recommend Wells G-O3 RD2, G-04RD and G-13 on the Grayling Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Wells G-03 RD2, G-04RD and G-13 meet the AOGCC requirements for no flow status. Attachments: Unac~t No~ Amc .----- Oil & Gas {Division PO. ~ox 1902~7 Anc~orace. AlasKa 995 ~ 9-02~7 Te,eona6e ~gO~ ZT6-T6GO April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. A~chorage, A/f 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 ~ hope this will meet your needs. GSB/lew Yours very truly, sh ' egionalDrilling Manager CONDUCTOR GRAYLING DISTANCE &.DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W "Y" COORD. "X" COORD. WELL # FSL LEG #3: LAT = 60050' 22.569" LONG =151°36' 46.519" 2,502,352.30 212,272.70 1804 1 2 3 4 5 6 7 8 9 l0 11 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 G-26 1806 2,502,358.05 212,269.49 G-25 1810 2,502,358.77 212,273.94' G-24 lB10 2,502,356.46 212,277.80 G-20 1808 2,502,352.20 212,279.28 1804 2,502,347.99 212,277.68 G-36 1800 2,502,345.80 212,273.75 G-34 & RD 179'8 2,502,350.83 212,270.89 G-23 & RD 1803 2,502,354.60 212,272.33 G~33 1806 2,502,351.47 212,274.88 G-27 & 28 1803 LEG #4: LAT = 60°50' 22.832" LONG =151°36' 48.042" 2,502,380.80 212,197.90 1831 13 14 15 16 17 18 19 20 21 22 23 24 LEG #1: LAT = 60o50' 23.575" LONG =151°36' 4Z.505" ' LEG //2: LAT = 60o50' 23.313" LONG =151 °36' 45.982" FEL 1409 1413 1415 1415 1412 1408 1404 1402 1'404 1408 1411 1409 1407 1486 2,502,374.34 212,196.66 G-14A 1825 1487 2,502,376.65 212,192.79 G-19 1827 1491 2,502,380.90 212,191.32 G- 1 3 1831 1493 2,502,385.11 212,192.92 G-15 1835 1491 2,502,387.30 212,196.85 G-5 1838 1487 2,502,386.45 212,201.28 1837 1483 2,502,382.96 212,204.12 G-3 1833 1480 2,502,378.46 212,204.05 G-2 1829 1480 2,502,375.05 212,201.11 G-11 1825 1486 2,502,378.50 212,198.27 G-lO 1829 1483 2,502,381.63 212,195.72 G-17 & RD 1832 1488 2,502,382.27 212,199.71 G-7 1832 1484 2,502,455.60 212,226.40 1906 (Reserved for Compressors) 2,502,427. l0 212,301.20 1880 37 2,502,421.45 212,297.82 G-12, RD & 2 1874 38 2,502.,424.94 212,294.98 G-31 1878 39 2.502,429.45 212,295.05 G-4 1882 40 2,502,432.85 212,297.99 G-1 1886 41 2,502,433.57 212,302.44 G-9 1886 42 2,502,431.26 212,306.31 G-18 1884 43 2.502,427.00 212,307.78 G-14 1880 44 2,502,422.80 212,306.18 .......... G~30 ........... 1876 '-- 45 ....... -~502,420.60 ............. 2i2,302.25 ........ G-8 & RD 1874 46 2,502,425.63 212,299.39 G-6 1879 47 2,502,429.40 212,300.83 G-32 1882 48 2,502,426.27 212,303.38 G-16 1879 1458 1383 1386 1389 1389 1 386 1382 1378 1376 ~]378 1382 1385 1383 1381 '"", STATE OF ALASKA '-' · ALASk.. OIL AND GAS CONSERVATION COMM...,$1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other~ 2. Name of Operator 5. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA dba UNOCAL 99'KB Above MSL Feet 3. Address 6. Unit or Property name P.O. Box 190247, Anchorage, Alaska 99519-0247 Trading Bay Unit 4. Location of well at surface 1831' N & 1493' W f/SE Corner Section 29, T9N, R13W, 7. Well number G-13 At top of productive interval Top Hemlock: 3469' N, 1836' W f/SE Corner SecLion 30, At effective depth T9N, R13W, S.M. At total depth 3710' N, 2098' W F/SE Corner Section 30, T9N, R13W, S.M. 8. Approval number 568 9. APl number 50-- 133-20127 10. Pool McArthur River Field/Hemlock 11. Present well condition summary Total depth: measured true vertical 12,000 feet Plugs (measured) 9,996 feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11,994 feet Junk (measured) 9,991 feet Length Size Cemented Measured depth 365' 26" Driven 365' 602' 17-3/4" 750 sx 602' 5115' _13-3/8" 1890 sx 5115' 11,350' 9-5/8" 1100 SX 11,350' 780' measured true vertical 7" 300'SX Upper Most 11,370' Lower Most 11,660 Upper Most 9,462i Lower Most 9,700' Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 11,220'-12,000' 3-1/2", 9.2#, N-80 @ 11,361' Otis Ball Valve @ 293' Baker Perm. pkr. @ 11,307' ~ue Verticaldepth 365' 602' 4465' 9445' 9348'-9946' RECEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A JAN 0 6 1 87 ~aska Oil & Gas Cons. C0mmJss/0! A.,~,chorage 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 575 -0- 275 1010 120 Subsequent to operation 720 550 14. Attachments Daily Report of Well Operations 520 1 O0O 1 5Q Copies of Logs and Surveys Run [] 15' I herTZ that the f°reg°ing is ~'u~~cOrrect tO the best Of my knOwledge Signed .~~~ Title Drilling Superintendent Form,~4 Rev. 17 Date12/31/86 Submit in Duplicate DAILY REPORT OF WELL OPERATIONS 12/16/86 12-16-86 11657 'ETD 12-17-86 Commenced 9.perations at 0200 hours 12-15-86. Rigged up on G-13. Tested surface euipment to 3000 psi. Ran in hole to 500' with 2.57" OD diamond bit and 2-3/8" Navidrill. Broke circulation with 6% KCl and filtered injection water. Ran in hole and tagged scale at 9045'. Cleaned out to tubing tail at 11,361'. Continued running in and tagged fill in 7" liner at 11,574'. Tripped for jetting tool. Ran in with jetting tool to 11,574'. Cleaned out fill from 11,574' to 11,618'. Unable to clean out past 11,618'. Trip for 2.57" OD diamond bit and 2 3/8" Navidrill. Ran in and cleaned out from 11,618' to 11,657'. Unable to clean out past 11,657' Sweep hole with 40 bbl HEC pill. Ream shoulder ~t 11,623' and sweep hole with 70 bbl HEC pill. Tag fill at 11,657'. Began pulling out. POH with coiled tubing. Rigged down and moved to G-3. Released rig at 0500 Hrs. 12/17/86 STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMM.,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) UNOCAL Corporation 99' KB Above MSL feet 3. Address 6. Unit or Property name P. O. Box 190247, Anch., Ak. 99519 Attn- C. Lockwood Trading Bay Unit 4. Location of well at surface 1831' N & 1493' W f/SE Corner Section 29, T9N, R13W, S.M. At top of productive interval Top Hemlock: 3469' N, 1836' W f/SE Corner Section 30, At effective depth T9N, R13W, S.M. At total depth 3710' N, 2098' W f/SE Corner Section 30, T9N, .R13W, S.M. 7. Well number G-13 8. Permit number 68-57 9. APl number 50-- 133-20127 10. Pool McArthur River Field/Hemloc] 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 365 ' Conductor 602 ' Surface 5115 ' Intermediate 11,350 ' Production -- Liner ?80' 'Perforation depth: measured true vertical 12,000 9,996 11,994 9,991 Size 26" 17-3/4" 13-3/8" 9-5/8" 1, feet Plugs (measured) feet feet Junk (measured) feet Upper Most Perf: Lower Most Perf: Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Cemented Measured depth ~ueVerticaldepth Driven 365' 365' 750 sx 602' 602' 1890 sx 5115' 4465' 1100 sx 11,350' 9445' 300 sx 9462' ) 9700' ) ) ) ) ) 11,220'-12,000' 9348'-9946' ECEIYE0 NOV 1 3 1986 SEE ATTACHED SCHEMATIC Naska Oil & Gas Cons. C0mrnissi0n Anchorage 12.Attachments Description summary of proposal [~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation November 27, 1986 14. If proposal was verbally approved Name of ap/ver /? Date approved 15. I hereby cg, Cify~hat.t,he fo~egoin~is tr~.a~ect to the best of my knowledge S, g n ed y~ __~/~--~.~.,¢~/~////.~'/T, t I e Drilling Superintendent / ' _ --/ .... Commission Use Only Co.o.o~itions of apprC'val Notify commission so representative may witness I Approval No. / [] Plug integrity i-I BOPTest [] Location clearance , Date 11-10-86 Approved by Commissioner by order of the commission Date //-- Form 10-403 Rev 12-1-85 Submit in triplicate G-13 COILED TUBING CLEANOUT PROCEDURE 1. RU slickline and pull ball valve. 2, MU KCl-polymer workover fluid 3. RU skid pump unit to 1-1/4" coiled tubing unit. 4. Pressure test surface equipment to 3000 psi. Function test coiled tubing unit BOP system. 5. RIH with Otis Hydrablast tool on 1-1/4" coiled tubing to +500' and break circulation with KCl-polymer fluid. 6. Continue down hole and clean out scale to tubing tail. (Reciprocate and check pick up weight on coiled tubing after every 20' drilled to insure no bridging. If returns are lost during operation turn on gas lift and reestablish circulation. Use nigrogen to provide additional lift if needed.) 7. POH with coiled tubing and RD. Replace ball valve. 8. Return well to production and move over to G-31L. 11-10-86 0173D RECEIVED N. OV ! 3 1986 Oil 8, ~as Cons. Anchorage VJELL TgUS G-13 ' CASING & ABANDONMENT DETAIL ,., o-o°' I1.1 Tubing Hanger at 39.00' --1 III.) 17 314', 0.312' Wall, Spiral Weld Casing at 602' / . IV.) 13 318', 61~,, J-55 Casing at 5115' i I I = V.) Top 7', 29~', N-80 Liner at 11,220' VI.) 9 5/8', 40~ & 47~, N-80 & P-110 Casing at 11,350' VII.) Bottom 7', 29~, N-80 Liner at 12,000' GL'--"~' 2 [ VIII.) CMT. PLUG AT I 1,700' ~ TUBING DETAIL ,v~ ! G~_--~. '~L 3 1/2'; 9.2~,.N-80 TUBING GL~ 4 1.) Otis Ball Valve at 292.72' 2.) Camco Gas Lift Mandrel at 2367.84' -- GLM 5 3`) Camco Gas Lift Mandrel at 4098.94' 4.) Camco Gas Lift Mandrel at 5256.37' GL'M. 6 '5.) Camco Gas Lift Mandrel at 6060.22' G L'--'"~'~ T 6.) Camco Gas Lift Mandrel at 6547.18° 7.1 Camco Gas Lift Mandrel at 7072.28' GLM s 8.) Camco Gas Lift Mandrel at 7565.84' GL'---~', 9 9.) Camco Gas Lift Mandrel at 8062.65' '----- 10o) Camco Gas Lift Mandrel at 8557.67' ~ ~ o 11.) Camco Gas Lift Mandrel at 9045.22' 12.) Camco Gas Lift Mandrel at 9536.66' GLM. 1'1 13.) Camco Gas Lift Mandrel at 10,054.70' GL'"---~-1'2 14.) Camco Gas Lift Mandrel at 10,553.26' 15.) Camco Gas Lift Mandrel at 10,924.43° -- GLM 1~3 16.) Camco Gas Lift Mandrel at 11,236.91' (~L~ 1,i I 17.) Otis 'XA' Sleeve at 11,272.90' -- 18.) Baker Locator at 11,306.O1' ~ 1'5 : 19.) Baker Perm. Packer with Seal Assembly -- from 11,306.94' to 11,326.31' v .~ GLm. 1 e - 20.) 3 1/2' Buttress Collar at 11,357.30' ' 21.) Otis 'Q' Nipple at 11,358.00' XA 17 ~ 22.) 3 1/2' Buttress Collar at 11,358.92' 23.) Otis 'XO' Sleeve at 11,359.62' ! ~ ~lo 24.) Bottom of Mule Shoe at 11,361.10' v,__ - PERFORATION RECORD C---I 2o e 21 DA TE INTERVAL CONDITION !'- -- '~ 22 X 0 23 10/06/68 I 1,600'- 11,660' HB ~4 4hpf Prod. 11,520'-11,600' HB ~3 4hpf Prod. ~ 24 11,410'-11,500' HB ~2 4hpf Prod. H B' 1 __~-[ ' 11,3 ? o'- t 1~o~, ~ '[~ HB .~ 1 4he, Prod. HB'2 ~--: HB-3 ~_~ _- HB-~ ~ NOV 1986 v,, ~ i:".'.:::,: ¥ :':!:"/i'.:.:'::.:.': LTM ' N~sg~ 0~ & G:~s Cons. C~,~miss~on Anchorage ' APe'D, _ ,, WELL TBUS G-13 ~T~ _--X,?.Y 19/8~'.. '" ~, WELL SCHEMATIC ', ' UNION' OIL COMPANY OF CALIFORNIA wellhead, it contains tour pairs of rams which are hydraulically-powered for opening and closing, The preventers also contain a manual override to enable the rams to be operated with loss ot hydraulic power or to be locked closed. The four pairs flora thc bottom up are: l-inch OD tubing rams to packoff around the tubing. [-inch OD lt~bing OTIS REELED TUBING UNIT BLOWOUT PREVENTER ASSEMBLY . t-! i i t . i , ~ - j malfunction, l-inch OD tubing cutter rams to cut the ~ubing ~hile it is in the wellbore if neccssa~', and a pair of blind ram~ to close when the tubing is out of the wellbore. This pre~enter a~embly has a side outlet or inlet to produce or pump through if necessary. ~e assembly is designed for H2S Sec'ice and has a 5000 psi working pressure rating. M~ 99t OTIS ENGINEERING CORPORATION BLOWOUT PREVE~TER ASSEAtBLY -I Training BLIND RAM/ i CI~TTER i~AM: I OLD. PIPE '~,of.i ALASKA D~PARTMENT OF NATURAL RESOURCES DivSsion of Oil and Gas '-.-'i'~c. TO, ~ ' =y::.... .. .- 'Y- ....... rector . · "Thru: Hoyle H. Hamilton DATE , April 1, 1976 ' Chief Petroleum Engineer FROm Russell A. Douglass ~' ~ SUBJECT, Platform inspection, Petroleum Engineering Consultant Union Grayling ~!i!i~i"-i:'~ Tuesday, March 30, 1976 - TraVelled to .the Union Grayling platform. Purpose of. :;,i.:-~:ii~:i,i': ~=..~y trip' was. to-witne'ss-~operatJon of subs.urface and surface safety valves and '.~;?- obserVe caSinghead pressures.Tand, production ~tests.. Tested a total of 23 surface and subsurface safety valves. All 23 surface safety valves tested okay. Three .of .the subsurface valves failed. These · failures were located in wells G-l, G, 7, and G-15. Several casinghead pressures .i~,??:~~'' in excess of 200 psig were :.observed, A summary of my observations is attached. ~.~.~'"~"'~' ! c°mPleted a field inspectiOn report which I gave to Bob Smith, production ? sup~rvi'sor. I, required him to repair, or replace the valves in wells G-I., ~:? G-7,'and G-15. I also recon~ended he bleed .down those wells with excessive :' caSfnghead pressures. A copy ;of the .repor. t is.attached. Pr~uction test data for the following wells was observed: -':.: Wel.1 G-30S ~y~erage. pil~..rAte_ 2610 ~:.~..,~ 1536 ..~ 765 ApI...gravi ty 26.0 ...... 32 9.5 ._ 30 . .. , 9.5 30 In sunlnary I witnessed safe'ty.~,:'valve .operations, castnghead pressures, and . production tests on the Union Gra~.iing]platform. Three. subsurface safety valves .~... :...;...... failed to operate successfulLy~ ........ '"' ....... ' .... ~'~ ....... -~-..:. . ,, Attachment ...... . . RAO:bJm OP~i Yes Location i!.Sign' .-... ' HoUs Re~SerVe:pi · Wells ;~ I.,:.BOP-E g'-se fluid~( Hyd;.vCC btl s, . ~:, ~.-. , ..!~¢.!:.'~.,'.:.'ps~' co-- 6i7 ........ 20. Dril.lin.q spool .... '::.,;'?i:,,,~'.!o'Utl "' ~.~:6~.?:'Subsurface-No. Wells. r21 "Kill Line-( )/Check valve .:~!-_) .. (~-l:'.Well Test Data ': .;... ..~.: 22 ;-Choke Flowline ( ) HCR val ( :';..'..;' 7':-"Wel Nos.~ .... ' .-;:..,.,.:,~,'"_:."-'4:r..? ( ) '": (', ).::'-:~::~'1: 23.~ Choke-Manifold No. valvs flas__ (~'):, ( 8"Hrs obs'e~,',' , -, , ' , -( )-~;"(")~ :":r:'24' 'Chokes-( )Remote( )Pos (,~d.i" (,~')~' ( ) -'9: BS&W',.r '-.;',,~ 2", "~. , - '?~!( -)'~.' (.::)'~!i~': 25.. Test Plug-( )Wellhd(' )cso( )no'ne (L).~:.() ::-']lO,..Gr..Bbls. ,.. , ," .'-f'.:,~:::;'--'!i() !-i.-('i:;):.?i.~6.'Annular'Pre'venter, .'.~..ps~g:~i,,;.. ,... ..:;:.::...~!:'..' '.' ¥-':,..i:'i.'....". (-:_) Fi na~an--~-o-~m~ -' .---.r~ ':'~;., ( )??: (.-.~:.) ~;"'27.. B 1 i nd Rams,~s i g ." . ,':.. ;?., '(~?; ) :.'~?~.'( ~ )/':_:~' 'i 1'?' P~'.' '~. '?::' ( ).':~, (::;:):~:~: 28~:': P i pe, Rams ' ps i g ~.t ~:-~ ~;:,....~:,:,.. -(~)-':.. (')' ':::: 1.2.'~ Water well-('-.)Capped( )plugg6d ( ..):.'~,~; (;?)'f~::'?..29, :'KellY &. Ke~°ck .?~;'~?~.~t'"p.Sig (f: ).: -'.( )."-".13, ' Clean,up · ... ' -': -,' (':)'"~'.~-.(:)?-~:,"30. Lower Kelly val've....' psig ().~'~,(.) ,..~: 14'." Pad-leveled -. :'~L~: -','.]"'- . ,-.:" ( '- ),;?: (~'.) ::~<'~ 31.;': Safety Floor valve~-( )BV (.]Da'~ Totat:/.'inSpeCtTon 'observation .'tilne-~/] :: (~]~daYs ..._lot~'l-' -number... 1 eaks and/or, equip, 'failures Remar.ks ~ . .~. .-; ~ .... · - .. . ,.,~ / . . - , cc: ~) z~-,',,, ~.~>,vNotify in- ~ days or when read~ Inspected by/Pi ~,~,.~Date - ;.~.. .... - . ' ..~ .. Dear Mr. Marshall: Union Oil and Gas Division: Western Region Union Oil Comp~ of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union October 22, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Enclosed for your files are two (2) copies each of the Well Histories for the following wells: Trading Bay Unit State G-15 (WO) Trading Bay Unit Stat~-~-'~(WO) Trading Bay Unit State G-2 (WO) Trading Bay Unit State G-21 (WO) Trading Bay Unit State G-23 (WO) Trading Bay Unit State G-23 Trading Bay Unit State G-22 Trading Bay Unit State K-21 Kenai Untit #21-6 (WO) Kenai Unit #33-30 (WO) Kenai Unit #43-7 (WO) Very truly yours, Jim R. Callender District Drlg. Supt. sk Encl. (22) · cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. - TBU only Skelly Oil Co. - TBU only Phillips Oil Co. - TBU only Standard Oil Co. USGS - Rodney Smith Union Oil and Gas....~.jsion: Western Region Union Oil Compan) California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union September 16, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Marshall: Enclosed for your files are the required monthly and completion reports for the following wells: TBUS G-15 (34-19) TBUS G-13 (32-30) TBUS G-2 (34-29) TBUS D-2A (13-5) TBUS K-21 (21-28) Monthly Report (P-4) Sundry Notice (10-403) Monthly Report (P-4) Sundry Notice (10-403) Monthly Report (P-4) Sundry Notice (10-403) Monthly Report (P-4) Monthly Report (P-4) Completion Report (P-7) Sketches of Producing Zones sk Encl. cc: Marathon Atlantic Richfield Amoco Production Skelly Oil Phillips Oil Standard Oil USGS-Rodny Smith Very truly yours, / David A. Johnson Drlg. Engineer Form 10-403 REV. 1-10-73 Submit "Intentions" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL I---J OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 We~qt qth Avenue; Anchorage, Ala~qka 99501 4. LOCATION OF WELL At surface Conductor #15, Leg Rm. #4, 1831'N & 14931W from the SE corner. Section 19: TgN, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20127 6. LEASE DESIGNATION AND SERIAL NO. ADL-17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME T~'ad~n~ R~3r TTt~* 9. WELL NO~. - - - State G-13 (32-30) 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 30: T9N, R13W, S. M. 12. PERMIT NO. 68-57 )OFt, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT' SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated (Sate of starting any proposed work. 5 6. 7. 8. . 10, 11. Skidded rig #55 over well TBUS G-13, Conductor #15, Leg. Rm. #4. RU & killed well w/ 65#/cu. ft. W@ fluid. Installed BPV. Removed x-mas tree. Installed & tested BOPE. PU on 4 1/2" tbg. & released 7" X 3 1/2" hyd. pkr. @ 11,284'. Pulled & laid dwn. 4 1/2" tbg. & accessories. CO 9 5/8" csg. to top of 7" liner @11,219'. CO 7" liner to ll,700'ETD. Isolated 7" liner lap @ 11,219' w/ 7" RBP & 9 5/8" test t~ols. Diff. tested liner lap-ok. CO wellbore to ll,700'ETD. RIH w/ 7" RTTS. Tested pkr. seat between Hemlock Bench #2 & #3 from 11,500' to 11,520' for isolation. Failed to test. Fracture treated Hemlock Bench gl through #4. CO wellbore to ll,700'ETD. Completed well w/ 3 1/2" gas lift assy. & returned well to production. Completed operations @ 6:00 pm, 8/28/75. DAJ for Ji' ,rr~. Call,haler TITLE Dist. Drlg. Su. pt. DATE- 9/1/75 (This space for State office use) ~PPI~OVED BY , CONDITIONS OF APPROVAL, IF ANY: T IT LEI DATE See Instructions On Reverse Side ~orm No. ~.~'Y. 3- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMAAITTEE SUBMIT ]~N DUPLICA'I~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I._. WKLL W~:LL OTHER ,. N~z OF OV~RATO~ UNION OIL COMPANY OF CALIFORNIA 909 West 9th Avenua. Anchcma~ Alt '4 LOCA~ON or wm~L ' ~' ' 99~01 Conductor '#15: Leg Rm. #4, 1831'N & 1493'W from the SE corner. Section 19: T9N, R13W, S. M. APl NUMERICAL ~ODE 50-133-20127 LEASE DESIGNATION AND SEi~IAL NO. ADL-17594 '? IF INDIA~ ALOTT'EE OR TRIBE NAME 8. L~IT F.a~'{M OR LEASE Trading Bay Unit 9 WELL NO State G-13 {32-30) l0 FIFJ~D AND POOL, OR WILDCAT McArthur River Field-Hemlock 11 SEC, T.. R. M. (BO~'TOM HOLE .Section 30: T9N, R13W, S. M. 12, P~gl~MIT NO 6R-q7 13. REPORT TOTAL DKPTH AT F2XTD OF MONTH. CHA~NGES IN HOLE SIZE, CASING AND C~MgNTING JOBS INCLUDING DEPTH SET AlxrD VOL~ USED. PERFORATIONS. TESTS A3q'D RESULTS FISHING JOB~ SUq~K IN HOLE AND SIDE-T]~ACKED HOLE A2~D ANY OTH]gR SIGNIFICANT CH3kNG~ IN HOL~ CONDITIONS 8/9/75 12,01 I'TD 11,700'ETD Cmt. Plug (Footage 0') Commenced operations on TBUS G-13 @ 12:01 am, 8/9/75. Skidded rig. from TBUS G-15 to TBUS G-13. RU WL unit. Pulled ball valve & gas lift valves & closed gas lift mandrels. Ran Gamma'Ray Collar Log from 11,645' to 11,316'. Opened "XA" sleeve @ 11,242'. Killed well w/ 65#/cu. ft. 5% KCL WO fluid. Installed BPV. Removed x-mas tree. Installed & tested BOPE. PU on 4 1/2" tbg. string. Unable to release 7" X 3 1/2" Guiberson RH-1 hyd. pkr. @ 11,277'. RU Dialog. RIH & cut 3 1/2" tbg. @ 11,255'. 8/10/75 12,011'TD 11,700'ETD Cmt. Plug (Footage 0') Pooh & laid dwn. 4 1/2" & 3 1/2" tbg. & accessories. RIH w/ 5 3/4" OS w/ 3 1/2" grapple. Worked over & engaged fish @ 11,255". Jarred pkr. free (3 hrs.). Pooh. Rec. all of fish. RIH w/ 6" bit & 7" csg. scraper. CO fill from 11,650'- 11,700'. Circ. &cond. mud. 8/11/75 12,011'TD (Footage 0') Pooh w/ bit & scraper. RIH w/ 7" RBP & 7" sqz. ll,700'ETD tool @ 11,515' to test blank 11,500'-11,520' between Hemlock Cmt.Plug Benches #2 & #3 for potential pkr. point for frac. treatment. Press. annulus above tool. Hemlock Benches #1 & #2 taking fluid @ 1600 psi. Press. DP. Blank 11,500'-11,520' communicated w/ 4700 psi. DP while maintaining 1600 psi on csg. Released sqz. tool & retrieved. RBP. Reset 7" RBP @ 11,360' to test 7" X 9 5/8" liner lap. . Set 7" sqz. tool @ 11,230'. Tested 7"liner & RBP to 4000 psi-ok. Released sqz. tool. Tested 9 5/8" csg. & 7" liner lap to 3000 psi-ok. Pooh w/ sqz. tool. RIH w/ 9 5/8" DST & 1000 psi wtr. cushion. Set tool @ 11,197' & press. DP to 1000 psi _, ,, w/,~ga_s. Opened tool & bled off ga.s cushion. Diff. tested 7" S,G~~--'?-f~~//~~~ Dist. Drip. Sunt ~ 9/]/75 NOTE--Report on this form is required for each calendar monthj regardless of the Itatus of operations, and must bo flied In diJpli¢(Ite with till oil and gas conservation committee byt#e 15th of the suQceeding month, unlel~ ~therwise d~rected. Union Oil and Gas D"'"qon: Western Region Union Oil Company ot California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union M.ay 16, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: TBUS G-13 (32-30) Dear Mr. Marshall: Enclosed for your approval are three (3) copies of the Sundry Notice & Reports on Wells (Intent) for the above captioned Grayling well. sk Encl, (3) cc: Marathon 'Atlantic Richfield Amoco Production Phillips Petroleum Skelly Oil Standard Oil. Rodney Smith - USGS Very truly yours, Jim R, Callender District Drlg. Supt. OIL /',ND GA~ ANCHORAG~ Form 10-403 REV. 1-10-73 Subnlit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to clrlil or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OW~LL.L[~WELLGAS g OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA. 3. ADDRF-..SS OF OPERATOR 909 West 9th Avenue~ Anchorage, Alaska 99501. 4. LOCATION OF WELL At surface C. onductor #15, Leg Rm. #4, 1831'N & 1493'W from the SE corner. Section 19: TgN,.R13W, S. M. 13. ELEVATIONS (Show whether DF~ RT, GR, etc.) . 99' RT above.MSL ' ::' · · 14. Check Appropriate Box To Indicate Nature of.Notice, Re 5. APl NUMERICAL CODE . 50-133-20127 6. LEASE DESIGNATION AND SERIAL NO. ADL-17594 7. IF INDIAN, ALIO/TEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME TTading. Bay Unit .... . ,.' I 9. WELL NO. State G-13'(32-.30) . 10. FIELD AND POOL, OR WILDCAT McArthur River Field-Hemlock 11. SEC., t., R., M., (BOTTOM HOLE OBjEIcTIv[~} Section 30: T9N, R13W, S. M. 12. PERMIT NO. 68-57 ~ort, or Other Data NOTICE OF INTENTION TO.- TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: wATER SHUT-OFF REPAI RING WELL FRACTURE TREATMENT ALTERING CASING sHOOTING OR ACiDIZING ABANDONMENT* (Other) _ . (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS {Clearly state alt pertinent details, and give pertinent dates, including estimated date of starting any proposed work. PLAN OF PROCEDURE: 1. Skid rig #55 over well TBUS G-13, Conductor #15, Leg Rm. #4. 2. RU & kill well w/ 65#/cu. ft. WO fluid. 3. Install BPV. Remove x-mas tree. Install & test BOPE. 4. PU on 4 1/2" tbg. & release 7" X 3 1/2" hyd. pkr. @ 1!,2~4'. Pull & lay dw-n. 4 1/2" tbg. & accessories. 5. CO 9 5/8" csg. to top of 7,' liner @ 11,219'. CO 7" liner to ll,700'ETD. 6. Isolate 7" liner lap @ 11,219' w/ 7" RBP & 9 5/8" test tools. Diff. test liner lap. 7. Sqz. 7" liner lap if determined necessary from test. 8. CO wellbOre'to iI,700'ETD. 9. RIH w/ 7" RTTS. Test pkr. seat between HemlOck Bench #2 & #3 from 11,500' to 11,520' for isolation. - 10. Fracture treat Hemlock Benches #1 through '#4 as. determined from pkr. seat. 11. CO well. bore to ll,700'ETD. 12. Complete well w/ 3 1/2" gas lift assy, & return well to production. ESTIMATED OPERATING TIME: Sixteen (16) Days. 16. I hereby c.p~fy that the fo.k'egolng is true and correct IGNE /.~ J i~'.'.l~. ~'Callencler . {thi~ space for State offica u~) cONm~°~s o~0 ~, -'~ ,'- ~ ' '~'~' ~ instru~ions On Reve~ Side TITLE Dist. Drlg. ,Supt. . DATE .5/15/75 ,, ANCHORA~ SUNDIIY NOTi~S AND REPORTS ON WELLS (I~ not Use this for for propo~ls ~ driH or to deepen, or plug back to a diffierent reservoir- Use "~PPLI~ATION FOR PFaff/lIT--" for Such proposals.) 2. IgAM~.. OF OPEB~TOR .Union 0, il, Compan7 of California 3. ADDEEgS OF oPERATOR 507 W. Northern Lights Blvd. 4. LOCATION. O'F WELL Ats~a~Conductor 15, Leg 4, 1831'North & 1493'West from SE corner Section 29, T9N, R13W, SM, ., {3. ELEVA~N~ (Show whether DF, RT, Gl{, etc. RT 99' above MSL 14. ?. IF INDIA.N, .a~I~O~I'~ OR TRIBE 8. UNIT~ FABAVI OR LEASE NAME Trading Bay Unit 9. V~mL No. State G-13 (32-20) 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 30, T9N, R13W, SM. [2. ~ER,M~T No. 68-57 ~orl', or .O~her ,Dat'~ NOTIC]~ OF INTeNtIOn/ TO : ~UBREQUENT REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SH0{)T OR ACIDIZE ABANDONS SHOOTING OR ACIDIZING ABANDONME]~Ts nEPAm WmLL CI~ANI}~ PLANS (Other) (NOT~: Report results of multiple completion on Well (Other) Com~letion or Recompletlon Report and Log form.) ~ . ~5. wsC~ez'pn°~°s~ oR C0~fPLZ'~ZV OP~RATW~S (Clearly state all pertinent details, and ~lve ~rtinent dates, including estimated date of starting any pro~d work. ' Upon initial completion, G-12 failed to flow. Gas lift equipment was installed, and an unsuccessful attempt made to produce the well. During February 1969, the Hemlock Zone was thru tubing reperforated and well returned to production on gas lift. Water cut increased from 45% to 86%. Temperature surveys indicated bottom wate~ entry through the lower interval of Hemlock perforations. Moved rig to G-13 for repair 9/13/69. Killed well w/oil base mud. Pulledztubing. RIH w/oe~ to 11,954'. Laid 100 sx cmt plug across perforations from 11954' to 11420'. DreSsed off cmt plug to 11700. Schlumberger reperforated w/4" carrier jets, 4 hpf, 11370'-11400', 11410'-11500', and 11520'-11660'. Reran tubing and gas lift equipment. Reinstalled & tested tree. Returned well to production on gas lift. RIG REL.EASED 7:00 PM 9/18~6~, Production Test 9/27/69:756 BOpD, 4.2% cut, 502 mcf; on gas lift. DIVI$1ON oF oI[ AND GA$ 16. I hereby DATE (This Rpace APPROVED BY DATE 9/29/69 See '~nstrucfions On Reverse Side Appr,~ved Copy Re: urned Form P--3 Form P--$ ~ 17~. 9-30-67 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATION; COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a difflerent reservoir. Use "APPLICATION FOR' PEIL!ViIT~" for such proposals.) 0IL OAS WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Ak. 99503 8. UNIT, FA17.~ OR LEASE NAME FILE" _ Trading Bay Unit '-= 9. WELL NO. Staee C-13 (32-30) , 4. LOCATION O,F WELL 10. FIELD ~ FOOL, OR WILDCAT Atsurface Conductor 15, Leg 4, 1831'N and 1493'W from SE corner section 19, T9N, R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 99' RT above MSL Check Appropriate Box To I~ndi,cate Nlature of N~otke, Re McArthur River - Hemlock tl. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sect. 30, T9N, R13W, SM 12. PEB2VIIT NO. 68-57 :ort, or'Other 'Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ] I PULL OR ALTER CASING FRACTURE TREAT ,MULTIPLE COMPLETE SHOOT OR ACIDIZE J J ABANDON* REPAIR WELL ~ CHANGE PLANS (Other) WATER SHUT-OFF ~ REPAIRING WaLL FRACTURE TREATMENT ALTERING CASINO (Other) (NOTE: Report results of multiple, completion on Well Completion or Recompletion Report and LOg form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Upon completion, Trading Bay Unit State G-I~ failed to produce as anticipated. Current production averages 630/350 BOPD with a 45% cut. Temperature surveys indicate bottom water entry through the lower interval of Hemlock perfs resulting in zone damage and severe loss of productivity. It is proposed to plug'back and isolate the bottom wet perforations, and reperforate the remaining Hemlock intervals in inverted emulsion fluid to increase productivity. PROPOSED PROGRAM 1. Move rig over hole. °~'~ ~']~q 2. Install and test BOE. 3. Change over to 68# salt water above packer. D~i$1ONOFOI/ANDC/,$ 4. Pull tubing. 5. Clean out to bottom. 6. Equalize a cement plug from 11,950' to 11,700' across loWer wet perforations (11,770' to 11,740'). 7. Drill out excess cement to 11,730~. 8. Spot inverted emulsion fluid from 11,730' to 10,500'. 9. Reperforate the following zones ~n invert~luidusing 4,', 4 hpf, hyperJet carrier guns: 11,370' - 11,400'; 11,410' - 11,500'; 11,520' - 11,720'. CONDITIONS OF APPROVAL, L]~ ANY: DATE See 1,nstructions On ReVerse Side APproved Returned TO' STATE OF ALASKA 'I'~ n,,: ...... ,...,~ }',.orcw;tl~, are th:?. Gel ~,ow:,ng- P.,~n "':,o. rxnal _ _ - _ _ h~;C c~p4-.. ~..~ ;.r,,~7 '';'~'' " ~ ' '~ ' ' m',' qonic/C,~]i,' .... ,o, . Compensated Formation Density ~. ~,.'~ ....... . ~-~ P, o~, ~m~ ,fy ,, ~ a::'o; os/Ca I iper Cement Bcnd I,o2 ~,,,~erlog 3 ,,,t,a log Core ~es-'"<ptions, Sidewnl~ Core Analysis Fore, at i on ~o>tS D;.., ..... v.~'"i ona~. Surveys Core ChiCs Sample Cut At.. ~.NO,', LLDt,~:u: RECE ? PT ...... ' .... ' ~ ,~c,ua,, REC .... TO / Union Oi! & ~ Pi '; ..... ',~.~e' ...... :~ V S~.Op. - ~'~:OS+~''~'~ 'jOri ,,'i3t rlc~. - S~C Attn: A .... borage :~1 99~03 Carlton Union Oil Company:'~',California 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Telephone (907) 277-1401 'February 14, 1969 FI k.E~. State and Federal Agencies Trading Bay Unit Participants (Mailing List Attached) Re: Repair G-13, Grayling Platform Gentlemen: Enclosed please find a record of repair on well G-13, Grayling Platform, McArthur River Field. BET/dp Very truly yours, B.E! Talley ~ Dis trict Dri~/'l lng Superintendent Encl. (2) FEB 1 v 969 VISION OF OiL AND GAS DI ANcfiORAGI~ FORM 401-ANC-W (8/67) Mr, T.Ro Marshall, Jr. DIVISION OF OIL & GAS 3001 Porcupine Drive Anchorage, Alaska 9950_1, Mr, W,J. Linton P.O. Box 259 Anchorage, Alaska 99501 MAILING LIST PART lC i PANT S Mr. To,,n Cha!lon~;.r biAP '~'-~0~'' 0i' L P,O. Box 2380 Anchorage ) Mr. L.E. Wilson ATLANT c vr~li~'~rt'r) c-,f~.~-~x~v Bo.~ 360 Anchorage, Alaska 99501 Mr. B.J. Pope e"r~',;'~r,n OiL c'c~x,rv*,N'V F:.v CAT TI; P.O. Box 7-839 Auchorage, Alaska 99501 Mr. C.Lo Cox SINCLAIR OII, CORPO~\TION 501 Lincoln Tower Building Denver, Colorado 80203 Mr, It.D, Redding PHILLIPS PETROI,EUbI COMPANY P.O. Box 419 Anchorage, Alaska 99501 Mr, F,J. Krebill PAN AMERICAN rE2~O~,EU~I CORP P.O, Box 779 Av,~-~- .... 'a~e, Alaska 99501 Mr, Lo] and Franz SKEI,I,Y OIL CO,~PANY 1860 I~incoln Stree. t Denver, Colorado 80203 RECEIVED FEB 1 7 I969 DIVISION OF OII, AND OJl~ Form STATE OF ALASKA S~brrd$ "I~rter~tions" in Triplicate & "Sut~equer~t Reports" in Duplicate OIL AND 'GAS CONSERVATIO,N, ,COMMI'I-rEE SUNDRY NrOTICES AND. REPORTS ON WELLS (DO not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION .FOR PERMIT--" for such proposals.) OIL ~ OAS WELL WELL OTHER 2. NAME OF OPERATOR Union 0il Company of CalifOrnia ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., A~chorage, Alaska 99503 ~L~CATION O,F WELL J" At surface Conductor 15, Leg 4, 1831' N and 1493' W from SE corner Section 19, T9N, R13W, SM. 1'3. ELEVATIONS (Show whether DF, RT, GR, 99'RI above MSL 14. Check Appropria~ Box To I,ndkate Nature c~ N~fice, Re '-- HLB .... - -- %. AVz NU~mPaC~ COD~- KLV 50-133-20127 Hwz ~__ ~L 17594 ~ - __ S, UNIT, FAB~I OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-13 (32-30) ' 10.FIELD A~D POOL, OR WILDCAT HcArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOL~ OBJECTIVE) Sec. 30, TgN, R13W, SM. 12. PEP,2VIIT l~O. 68-57 NOTICE OF INTENTION TO: TEST WATER SHUT-OF]~ I [ PULL OR ALTER CASINO FRACTURE TREAT j j MULTIPLE COMPLETE SHOOT OR ACIDIZE ~ ABANDON® REPAIR WELL CHANGE PLANS EUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CARING 6HOOTING OR ACIDIZING ABANDONMEI~T· (Other) (NOTE: Report results of multiple completion on Well (Other) Completion or Reeompletion Re~?rt and Lo~ form.) 'I~SCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including e~timated date of starting any proposed work. Upon initial completion, G-13 failed to flow. Gas lift equipment was installed, and an unsuccessful attempt made to produce the well. Producing characteristics indicated very little fluid entry existed into the wellbore. The Hemlock Zone was thru-tubing reperforated to improve productivity. RIG RELEASED from G-17 @ 6:00 PM 2/2/69. Move to C-13 for repair. Rig Schlumberger to reperforate Hemlock Oil Zone. Removed ball valve and gas lift valves. Thru tubing reperforated Hemlock from 11770-11740, 11720-11520, 11500-11410, 11400-11370. No increase in pressure upon completion of reperforating. Reinstall gas lift valves and ball valve. Prep to return well to production on gas lift. RIG RELEASED'from G-13 @ 10:30 AM 2/3/69. 16. I hereby certify tha- for true and Correct SIGNED~~2 TITLE Dist. Drlg. Supt. APPROVED B TITLE . .. CONDITIONS APPROVAL, IF A~: DATE 2/6/69 See l. strucfions On Reverse Side UNION OIL CO. OF CALIFORNIA ALASKA DISTRICT TO: State of Alaska FROH' _-lJniogr_Ol _P. _ ._ ~ ' : ' - Tran,.,m~,,ud'; *" -- 'ne_u,,.~,h'r~'"* are the following- Transmittal DATE- J)ecembe? WELL NAHE. Run No..____&__. Sepia Blue Scale 17 Induction Electrical Log --2w-- Dual Induction Laterolog BtlC Sonic/Caliper Log BHC Sonic/Gamma Ray . _____ BHC Sonic/ Caliper/Gamma Ray Log Formation Soni~ Log Density~Gamma Log Formation Density Log (Fd) Neutron Log Formation Neutron Log {Fn) CDM or tfigh Resolution Dipmeter CDM Safety Print CDH or Printout CD?.I or Polywog Pict CDH Polar Plots Proximity-Hicrolog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log bI~dlog Core Descriptions, Conventional, No. Core Descriptions, SidewalI Core Analysis Core Chips Sample Cut Drill Stem Test Directional Surveys VISION Ot~ OIL AND GAS DI ANCEO,%;-9E Re'ceipt acknowledged- ~x~t~/~_... Date' /2--/~" (: ~ Return receipt to' Union Oil Co. of California, 2805 Denal~ St. Anchorage, Alaska Rochelle Carlton 99S03 Ple~ao acktwwlodqo receipt ,and re~un~ .to...." Union Oil Co. of California 2805 Denali Street Anchorage,' Alaska 99503 Porn No. P--4 P~-W'. STATE OF ALASKA SUBMrr n~ DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL 2. NAME OF OPERATOR OTHER Union Oil Company of California ~,ADDREsSOFOPE~ATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCATION OF w~i.Y. Conductor 15, Leg 4, 1831'N & 1493'W from SE corner Section 29, T9N, R13W, SM. API N~E~CA/~ CODE. 50-133-20127 6. LEASE DESIGNA~ON AND S~IAL NO. ADL 17594 7, IF INDIAN, ALOTTEE OR TRIBE NAME 8. LrNIT,F~ OR LEASE NA~4E Trading Bay Unit 9. WELL NO. State G-la (32-30) 10. Fi~D AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., 1%5, (BOT'TOM HOLE OB, mC~ Sec. 30, T9N, R13W, SM. 12. PEI~MIT NO. 68-57 ... 13. REPORT TOTAL DPAP"I'PI AT END oF MON'I'PI, CI-IA2N'GES IN HOLE SIZE, CASING AND CE1VIENTING JOBS INCLUDING DEPTH SET ~ VOLLT~ US~T), PF-~Z~FO~TIONS, ~-ESTS ~ I{ESULTS, FISHING JO~, JUNK IN HOLE AND SIDE-q-R~%CKF~D HOLE A_ND A~Y OTI-I~R SIGNIFICANT CI-IAN-~ES IN HOLE CONDITIONS. TRADING BAY UNIT STAT,E G-,l,3 (32-30), OCTOBER .1968 Continued drlg 8-1/2" hole to 12011'TD. Ran Schlumberger DIL, LL-3, micro latero log, sonic HRD & density logs. RI to TD, circ& condition for 7" lnr. PO, run & cmt 18 its of 7" 29# N-80 buttress lnr w/shoe @ 12,000' & top hanger @ 11,220'. Cmt w/300 sx Class "G" cmt mixed w/CR-2. RI w/8-1/2" bit, fnd top of cmt @ 10,775, drld firm cmt 10775 to'top of lnr hanger @ 11,220'~. Press tstd lnr lap w/2400# for 20 min - OK. PO, RI w/6" bit, drld soft cmt fm 11,220-11,228. Drld hard cmt ll,900-11,954ETD. PO, ran Schlumberger GR-CBL. Ran 4-1/2" 12.6# N-80 buZtress ~b$. Hung w/tail @ 11,322' & pkr @ 11,287'. Set & tstd pkr - OK. Remove Bog. Install Xmas Tree. Perfd: 11,770-11,740; 11,720-11,520; 11,'500-11,410; 11,400-11,370. Installed flow line. RIG RELEASED: 6:00AM 10/6/68. Well shut in, would not flow,~awaiting gas lift installation. RECEIVED NOV.19 ]968 DIVISION OF OIL .AND 14.1 hereby cert~; th~ f~tf~g is true and correct S~GN~D I/il/Iff' / ~ =~ Dist. Drlg. Supt. s of operations, and must be filed in duplicate '-- .-----_ ______ ______ D~T~ 11/15/68 with the Division of Mi s & Minerals by the 15th of the succeeding month, unless otherwise directed. iii R E:C E IV ~orm P--7 !~7~ . ?.;~ SIiBMIT ~IN DUPLICATE' STATE OF ALASKA '!!i'~OV ~. ~ st ~uet lone o~ OIL AND GAS CONSERVA~ON ~~~NE~ WELL PLETIQ~_ ~,~ ~[ 17594 lb. TYPE OF COMPLE~ON: ~'d ' :~' [ 1 ,,.~ o,-, ,, :',: Trad. ay NAM~ OF OPERATOR ~ ~ ,~ ~ 507 ~, so~th~ ~.*~-~ ~va. ,~~-~. ,1~..~ ~4. LOCATION OF WE~L ~eport location clearlp a~d ~ ~~e w~-an~ atEte r4eutre~ents)* · t .~-~ C~d~tor 15, ~ ~, 1831'N a,1493'~ ~ SE corer . 29' ~ ':~. ' · ' ~ At total dep~ ~ ~ ; ~ ~'- L l~. P~XT NO. ~2014'~ ~879'H & 5885*~ o~ SuE~aee ~tt~. ~ ' 6~57 ' T~ D~H, ~ & TvD~9 9. ~LUG ~ MD & ~. ~ ~'X~ ~,~.,~ ~.. ~:~[~~ (~-~) ~7~o-~7~.(~6s~7~9) . ,~ ~. , ,. - s" F' =' -'i--- 'm 'i 9, ~ :' . ~ ( : ..... ~ ,~* _ _;, , ~:'~ ~,-520-~,720 ~~- heZes p~ ft. 11,7~0-~, 770 ~~ ~lee ~ · · ' -r '~ ~ , i ', .. ~ "' , . i.. Well ~ld not ~w~4 S~t In pe~~ ~e lift ~tn~~.' FLOW ~BING' ~mO P~S~ ic~~ O~BBL. 0~~.:: WA'rmB~. lOlL GRAVlTf-I 31. DISPOSITION OF GAS (~OJ~, 5led I0¢ fuel ve~ted, etc.) . . ]TEST 33. I hereb~ cert~yt~the ~oi~ and at~ched information Is cbmp~ete and co~re~t as determined from an:a,ai]ab]e records SIGNED - ' ,- TITLE D~t Dr . Supt. DATE ~ *(S~ Instructions aha S~ces lot A~gitio..l / ! State ,,,6-13 (32-30) ' 10. FII~LD ',,~"q'l~ POOL; OR WILDCAT-, Mcirthur aiver- a~ock 'u. ~:, ~i e:', ~., ~~ .o~ ' O~~) ' -' _.. I'I il INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item:. 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure= ments' given in ather spaces on this form and in any attachments. Items 20, tad 22:: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc.ducing interval, or intervals.~: 'top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, . show-: ing the additional data pertinent to such interval. It~m26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the lacatian of the cementing toal. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). "34. SUMM/LRY OF ~'ORMATION T~TS"~I~ICLUDIN(; INTiR~I., 7ESTE~. P~t.ESS~IRE DATA A~ ~OV~ OF OIL. G~. ' ' ~ ' 35. G~GIC MARK~" WA~ AND M~D . . NON~ H~I 11 370, c: ':~ ~ .... , . as. ~OR.E DATA, AqWACH BRIEF D~CRIPI~OHS.~ 0~' LITHOLOGY, POROSITY, FRAC~R~. APP~NT DIPS AND DETECteD SHOWS OF OIL. G~ . . . , ~ , ~ , , , ,-'.!i- - :'--' . UNION !OIL CO. OF CALIFORNIA · · ~ WELL-RECORD ._,, PAGE NO LEASE TRADING BAY UNIT STATE WELL NO. G-!3 FIELD ,-,~ ARTHUR RIVER CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 17-3/4" .312 Wall Weld Spiral-Weld 602 Cmtd w/750 sx Class "G" w/2% Ca.C12; 1~- ~0 ~ ~% .. CaC12. Cmt Circ., good returns. 13-3/8"I 61# '~ Seal lock J-55' 5115 See. History for Cmt Derail .9-5/s" 147" ,~,43.5 - 40# Butt'tess P-110 & N-S{ 11350 See History for'Details ' 7" - 29!/ ' Buttress N-80 12000 Cmtd w/300 sx CFR-2 4-1/2" .12.6# Buttress N-80 11322 See Tubing Detail .......... ~ERFORArlNG RECORD , DATE INTERVAL E.T.D. REASON PRESENT CONDITION .!0/6/68 11770-11740 ·11954 Open ~nr Prnduct~n .. 11720-11520 11500.11410 11400-11370 , · . · · . INITIAL PRODUCTION - 'DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE M~F GOR REMARKS · 10/10/!~8 Ooen slae~e above packer. Displace die'set with nitrogen Cio~d .=l~vo. Blew well do~m through ~,ell clean t~nk and flare line. · · · · · .,, , · __ _ · . _ · WELL HEAD ASSEMBLY TYPE: CASING HEAD:. Shaffer K.D. 12" 900 Series x 13-3/8" S.O.W. CASING HANGER: Shaffer 12" nominal - 9-5/8" Model KD. KS CASING SPOOL: TUBING HEAD- Cameron DC-B12 12" 3000# x 10" 5000#'w/5000# studded outlet TUBING HANGER: DC-FBB 10" nomir~.al 4-1/2" Buttress Bottom x 4-1/2"' EUE top TUBING HEAD TOP' .Single string sOlid block log type Cameron bottom flange to 5000# w/7" OD ~ASTER VALVES: seal pocket' RISTMAS TREE TOP CONN.: '~ 4-1/2" LUg- ?~,SE TRADING BAY UNIT STATE UNION OIL COHPANY OF CALIFORNIA I,£LL I LCOR PAGE No, 3 FIELD . _ .McARTHIIR RIVER FIRI,D ATE · 8/10/75 8/11/75 8115175 8/16/75 8/17/75 12,01 I'TD 11,700'ETD ~mt. Plug 12,011'TD 11,700'ETD Cmt. Plug 12,011'TD 11,700'ETD Cmt .Plug 12,011'TD. 11,700'ETD' Cmt. Plug 12,011'TD 11,700'ETD Cmt. Plug 12,011'TD I;~ETAILS OF OPERATIONS~ DESCRIPTIOHS & RESULTS (~mtage 0') Commenced operations on TBUS G-13 @ 12:01 am, gP//9/75. Skidded rig from TBUS G-15 to TBUS G-13. RU WL unit. Pulled ball valve & gas lift valves & closed gas lift mandrels. Ran Gamma-Ray Collar Log from 11,645' to 11,316'. Opened "XA" sleeve @ 11,2.42'. Killed well w/ 65#/cu. ft. 5% KCL W@ fluid. Installed BPV. Removed x-mas tree. Installed & tested BOPE. PU on 4 1/2" tbg. string. Unable to release 7" X 3 1/2,' Guiberson RH-1 hyd. pkr. @ 11,277'. RU Dialog. RIH & cut 3 1/2" tbg, @ 11.,255'. (Footage 0') Pooh & laid dwn, 4 1/2" & 3 1/2" tbg. & accessories. RIH w/ 5 3/4" OS w/ g '1/2" grapple. Worked over & engaged fish @ 11,255'. Jarred pkr, free (3 hrs.). Pooh. Rec. all of fish. RIH w/ 6" bit & ?" csg. scraper. CO fill from 11,650'- 11,700'. Circ'. &cond. mud. (Footage 0') Pooh wY bit & scraper. RIH w/ 7" RBP & 7" sqz. tool @ 11,515' to .test blank 11,500'-11,520' between Hemlock Benches #2 & #3 for potential pkr. point for frac. treatment. Press. annulus above tool. Hemlock Benches #1 & #2 taking fluid @ 1600 psi. Press. DP. Blank 11,500'-11,520' communicated xv/ 4700 psi. DP while maintaining 1600 psi on csg. Released sqz. tool & retrieved RBP. Reset 7" RBP @ 1!,360' to test 7" 'X 9 5/8" liner lap. Set 7" sqz. tool @ 11,230'. Tested7" liner & RBP to 4000 psi-ok. Released sqz. tool. Tested 9 '5/8" csg. & 7" liner lap to 3000 psi-ok, Pooh w/ sqz. tool. RIH w/ 9 5/8" DST & 1000 psi wtr. cushion. Set tool @ 11,197' & press. DP to 1000 psi w/ gas. Opened tool & bled off gas cushion. Diff. tested 7" liner lap to 2500 psi for'4 hrs. Rev. out. No formation fluid entry. Pooh w/ test tool. Released rig @ 12:00 Midnite from TBUS G-13 to TBUS G-15 for thru tbg. perf. of G-15 while waiting on frac. equipment. (Footage 0') ReCommenced operations on TBUS G-13 @ 12:00 Noon, 8/15/75. Skidded rig #55 from TBUS G-2 to TBUS G-13. Installed & tested BOPE. Retrieved 9 5/8" RBP @ 950' & 7" RBP @ 11,360'. (Footage 0') RU frac. equipment. Mixed YF60HC frac. fluid. RIH w/ w/ @EDP to 11,604'. Pumped &spotted 23 sx. of 20/40 sd. Alloxved sd. to settle. Tagged sd. @11,604'. Pooh. RIH w/ 7" RTTS & set @11,249' for frac. treatment. Tested lines & equipment to 8,400 psi. preceded frac. fluid w/ 48 bbls of 12-3 mud acid followed by 120 bbls of 2% KCL wtr. Frac. well while holding 2500 psi on annulus as follows. Initial rate- 9 BPM @ 2500 psi. VOLUME SAND CONCENTRATION RATE PRESS. 121 bbls. 0 9 BPM 3800 psi 166 bbls. 1/2#/gal. 11 BPM 3600 psi 120 bbls. l#/gal. 11 BPM 3500 psi ~.$6 bbls. 2#/gal. 11 BPM 3500 psi t66 bbls. 3#/gal. 11 1/2 3200 psi BPM 190 bbls. 4#/gal. 11 1/2 3100 psi BPM (FOotage 0') Displ. w/ 2%KCL wtr. Finalrate-6 BPM w/ 2875 psi. UNION OIL CQ' PANY OF CALIFO ' I^ £LL RECORD LF E . ~R.CtDING BAY UNIT STATE FlED McARTHUR RIVER FIELD 7 8/18/75 8 8/19/75 8/20/75 10 8/21/75 11 8/22/75 12 8/23/75 lB 8/24/75 ll,700'ETD Cmt.Plug 12,011'TD 11,700'ETD Cmt. Plug 12,011'TD 11,700'ETD Cm't .Plug 12,011'TD 11,700'ETD Cmt. Plug 12,011'TD ll,700'ETD Cmt. Plug 12,011'TD Il, 700'ETD Cmt. Plug 12,011'TD ll,700'ETD Cmt. Plug 12,011'TD 11,700'E'rD Cmt .Plug DETAILS OF OPERATIONS, DESCRIPTIOHS g RESULTS Total sd. used 76,600#. SI well. Let press, bled into formation. Bled to 900 psi & held. Rev. out & displ, well w/WO fluid. RU Scht, & ran GR Log. Tagged sd. bridge @ 11,371'. Ran 6" bit & ?~ csg. scraper. CO bridge @ 11,37i'. Had sd. fill from 11,397'- ll,?09'ETD. Circ. out sd. Pooh. RU Schl. & ran GR Log from 11, ?t)0~ -11, 215'. Logged radioactive frac. material from 11,376'- 11,400~' (Bench #1 perf. from 11,370'-11,400') & from 11,410'-11,446' (Bench ~2 perfs, from 11,410'-11,500'). Total frac. treatment in Benches #1 ~, #2. RD S chl. 0F~tage 0') RIH w/ 6" bit & 7" csg. scraper. Circ. btms. up @ ll,?~}~.~IgTD. Pooh. Laid dwn. DP '& rotary tools. RU Schl. RIH w/ ?~' guage ring & JB to 11,400'. Ran Baker 7" X 4" Model "D" perm. · pro~. pkr. & set @ ll,300'DIL. RU to run 3 1/2" prod. tbg 0Footage 0~') Completed running 3 1/2" 9.2# N-80 Buttress tbg. $~bbed into pkr. @ 11,300' & tested to 700 psi. Installed bali valve man .¢hreil a spaced out tbg. Installed BPV. Removed BOPD. Installed ~t tested 'tree. RU North Star WL. Ran shifting tool & opened XA sleeve { 11,272', Shifting tool backed off running tool while Pooh,' -fell a jammed in Q nipple @ 11,358'. (Footage 0~) Jarred shifting tool free from Q nipple @ 11,358'. Pooh wY shifting tool. Unable to pull or jar through XA sleeve @ ll, g?Z:" (apparent damage to shifting tool lost in hole). Released shit~t~ng tool @ Q nipPle @ 11,358'. Ran 2.73"OD guage. Unable top, ss XA sleeve @ 11,272'. Ran 2.695"OD guage. Passed XA sle'e'¥e ok, Closed XA @ 11,272"& tested ok. Reopened XA Sleeve. Ran Go-Int'l. 2.5"OD DP cutter & positioned @ 11,346' in tbg...jet, below seal assy. Attempted to cut tbg. @ 11,346'. Cut 'indicated on collar log. Tbg. tail failed to fall. Recur @ 11,347.5'. Failed to fall. Ran sinker bars & jars. Jarred-tbg. tail off ok. :(Footage 0') Jarred off tbg. tail & Pooh w/ sinker bars & jars. RU & displ, W@ fluid w/ filtered Inlet wtr. Closed XA sleeve @ 11,272'. Put well On gas lift @ 2:00 pm, 8/21/75. (Footage 0') Gas lited & tested well while deactivating Rig #55. (Footage 0') Gas lifted & tested well while deactivating Rig #55. 8 hr. prod. test, 8/23/75. GROSS NET CUT FM.GAS GOR GLR TBG/CSG. 2088 1952 6.5% 560 28-7 137--7 120 960 (Footage 0') Gas lifted & tested well xvhile deactivating Rig #55. UNI(X~ OIL C05DANY OF. CALIFORNIA I,£LL 'R[CORD L~ TRADING BAY UNIT STATE I'£LL ~0, G-~3 FIELD ~A~rHu~ ~v~.~ FIELD DATE ETD 14 8/25/75 15 8/26/75 16 8/27/75 ~7 8/28/75 12,01I'TD ]I,700~ETD Cra/. Plug 12., Oll~'TD 11,700'~ ETD Cmt.Ping ' la, 0 II'TD Cmt. Ping 12,011'TD ' 11, ?0 O ~'ETD Cm t. Plug DETAILS OF OPERATIONS, DESCRIPTIOI'iS g RESULTS (Footage 0') Gas lifted & tested well while deactivating Rigs #55 & #54. 12 hr. prod. test, 8/25/75. GROSS NET CUT FM.GAS GOR GLR TBG/CSG. 2040 1938 5.0% 245 126 1.473 100 940 (Footage 0') Gas lifted & tested well while deactivating Rigs #55 & #54. GROSS NET CUT FM.GAS GOR GLR TBG/CSG. 2° 2015 1910 5. ~ 500 262 1.514 100 915 (Footage 0') Continued deactivating Rigs #55 & #54. (Footage 0') Completed deactivating rigs #55 & #54. Released crews @ 6:O0 pm, 8/28/75. ~i-IUz i IJ 'UNIa I OIL CQ'CPA ' OF CALIFOf IA 'ELL RECORD LF E TRADING BAY UNIT STATE I'~LL G-13 FIELD _McARTHUR R!VER FIELD 9ATE JTS. 1 1 1 1 1 10 1 12 1 16 1 17 1 16 1 16 1 16 1 16 1 16 1 17 1 16 1 26 1 38 1 57 1 DETAILS OF OPERATIONS, DESCRIPTIOrtS g RESULTS TUBING DETAIL 3 1/2" 9.2# N-80 Buttress ~&.C. ~_eg .~ _Cp lg s. DESCRIPTION LENGTH Otis Mule Shoe 3. 15/16" X 3" .98 XO 8rd Pin 3 1/2" X 3" .50 3 1/2" Butt. Collar B 13/16" X 3" .70 Otis "Q" Nipple 3 3/4" X 2 5/8" .92 3-1/2" Butt. Collar 3 13/16" X 3" .70 3 1/2" 9.2# N-80 Butt, Tbg, 30.99 Baker 80-40 Seals 4" X 3 1/16" 19.37 Baker 7" X 4" Perm. pkr. set @ ll,300'DIL. Baker Locator 4 3/4n X 3 1/16" 3 1/2" 9,2# N-80 Butt, Tbg, Otis 3 1/2" XA 4 1/2~' X 2.750 3 1/2" 9.2# N-80 Butt, Tbg, Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt, Tbg, Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt, Tbg. Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt, Tbg, Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt, Tbg, Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt. Tbg. Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt. Tbg. Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt. Tbg. Camco Gas Lift Mandrel 3 1/2" 9,2# N-80 Butt. Tbg Camco Gas Lift Mandrel 3 1/2" 9,2# N-80 Butt. Tbg Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt. Tbg Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt. Tbg Camco Gas Lift Mandrel 3 1/2" 9,2# N-80 Butt. Tbg Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt. Tbg Camco Gas Lift Mandrel 3 1/2" 9.2# N-80 Butt. Tbg Camco Gas Lift Mandrel 3 '1/2" 9.2# N-80 Butt. Tbg Otis Ball Valve ,93 29.11 4.00 28.02 7.97 304.51 7.97 363.20 7,97 490.59 7.97 510.07 7.97 483.47 7.97 479.58 7.97 487.05 7.97 488.84 7.97 485.59 7.97 517.13 7.97 480.51 6.45 .797.40 6.45 1,150.98 6.45 1,724.65 6.45 2,070.70 4.42 'BOTTOM TOP 11,361.10 11,360.12 11,360.12 11,359.62 11,359.62 11,358.92 11,358.92 11,358.00 11,358.00 11,357.30 11,357.30 11,326.31 11,326.31 11,306.94 11,306.94 11,306.01 11,306.01 11,276.90 11,276.90 11,272.90 11,272.90 11,244.88 11,244.88 11,236.91 11,236.91' 10,932.40 10,932.40 10,924.43 10,924.43 10,561.23 10,561.23 10,553.26 10,553.26 10,062.67 10,062.67 10,054.70 10,054.70 9,544.63 9,544.63 9,536.66 9,536.66 9,053.19 9,053.19 9,045.22 9,045.22 8,565.64 8,565.64 8,557.67 8,557.67 8,070.62 8,070.62 8,062.65 8,062.65 7,573.81 7,573.81 7,565.84 7,565.84 7,080.25 7,080.25 7,072.28 7,072.28 6,555.15 6,555.15 6,547.18 6,547.18 6,066.67 6,066.67 6,060.22' 6,060.22 5,262.82 5,262.82 5,262.37 5,256.37 4,105.39 4,105.39 4,098.94 4,098.94 2,374.29 2,374.29 2,367.84 2,367.84 297.14 297.14 292.72 bHLLI 0 Pa~e No,~, , ? UNIOtI.oIL COFPANY OF CALIFORNIA 5ELL RECORD LF~E_ TRAP!NG_BAY__ Id,Nlm STATE .._ ¥~LL NO, G-13 FIELD . McARTHUR ,RIVER FIELD -_ DATE JTS. 368 Jts. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DESCRIPTION TUBING DETAIL Cont... LENGTH 3 1/2" 9.Z~ N-80 Butt. Tbg. 3 I/Z" 9.2~ M-gO Butt. Tbg. 3 ii2-" ~.Z~ ~-.~O Butt. Tbg. Cam~,~n ~g. Hgr. 240.42 4.10 8.15 1.05 39.00 3-6g J~_. ~f 3 1/2" 9.2# N-80 Buttress Tbg. 2 P~ps B ][/~2:"' 9.2# N-80 Buttress Tbg. Camco, Gas Lift Mandrels: 3 lf2'~' ~G ~6,00~'OD ~ 2.375"ID 3 I/Z'~' KB,~G 5.50"OD & 2.875"ID BOTTOM 292.72 52.30 48.20 40.05 39.00 TOP 52.30 48.20 40.05 39.00 --0-- · II I ~ll I~ II II I ..... I _ I II II IJ I iiil±j i i ii · 8 Tbg. Hgr. @ 39.00' 1. Ball valve, Otis @ 292.72' 2. Gas lift mandrel, Camco @ 2374.29 3. Gas lift mandrel, Camco @ 4105.39 4. Gas lift mandrel, Camco @ 5256.37 5. Gas lift mandrel., .Camco 0 6060.22 6. Gas lift mandrel, Camco @ 6547.18 7. Gas lift mandrel., C~mco ~ 7072.28 8. Gas lift mandrel, '.Camco @ 7565.84 9. Gas lift mandrel, Camco @ 8062 10. Gas lift mandrel, Camco @ 8557.67 11. Gas lift mandrel, Camco 0 9045.22 12. Gas lift mandrel, Camco @ 9536.66 13. Gas lift mandrel, Camco @ 10,054.70 14. Gas lift mandrel, Camco @ 10,553.26 ' 1'5. Gas lift mandrel, Camco 0 10,924.43 16. Gas lift mandrel, Camco ~ 11,236.91 17. XA 3 1/2" Otis, 4 l[2"OD X 2.750 ID @ 11,272.:90 18. Locator, Baker 4:3[4" X 3 1/16" @ 11,306.01 19. Pkr., Baker, perm, 7" X-4"' w/ Baker 80-40 seals 4:' X 3 1/16" @ 11,306.94.. (pkr. set @ ll,300'DIL) 20. Collar, Butt. 3 1/2", 3 13/16" X 3" @ 11,357.30". 21. "Q" Nipple, Otis 3 3/4" X 2 5/8" @ 11,358.00'. 22. Collar, Butt., 3 1/2", 3 13/16" X 3" '- @ 11,358 92' 23. X@ sleeve 8rd pin 3 1/2" X 3" @ 11,359.62'. 24. Mule shoe, Otis 3 15/16" X 3" @ 11,3'60.12'. _ Note: 19 20 21 22 23 1. Gas lift mandrels are: A. 3 1/2" KBMG w/ OD's of 5.50" & ID's of 2.875". 2. There are 368 jts. of 3 1/2" 9.2# N-80 Buttress tbg. in this well along w/ 2 pup jts. 3 1/2", 9.2#, N-80 Buttress Tbg. m - } iii~ii'ii I I I I i i i II I II i I I I I J I WELL SCHEMATIC AI~F'D' -- ......... TRADING BAY UNIT STATE G-13 (WO) ~....-_ __ ....... Started 8/9/75 Completed 8/28/75 Il I~ J ~ i ........... ~1 ' ' ~ ...... Ie . ~' NPT CONTROL OD. NATIONAL LINE BUTTRESS UNION OIL CO. OF CALIFORNIA ANCHORAGE, ALASKA '~' · · P. O. BOX 1212-- tlOUSTON. TEXAS 77001 · ~ · - UI~tlON OIL COHPAN¥ OF CALIFORNIA ' QUOTE #9-4474 ANCItORAGE, ALASKA · ' CAS ING PROGRAM -' It I/2"OD · I~TIONAL BUTTRESS W/1/8"NPT C'ONTROL LINE 'ORDERED UNIT PRICE J~&R'~NUHOIrR DESCRIPTION Al,lOUt,iT · SINGLE STRING TREE AS FOLLOWS · . XFAS TREE ASSEt4BLY 5000g'tP 1497.1I 20446 20 I0 I0 SP,OOL, TBG HD DC[,~ 12"3000#WP X 1497.1I I O~5000~MP W/2-2 O00#V/P STDD OUTL 12.83 6590.58 GASKET STEEL RING' R 54 12.83 · · '6.'23 6932 I STUD 1-7/8" X 14-I/2" -: 74.76 .. 1:7~ 5~2 ~ 29 NUT 1 '7/8" 41 .'7~ : 4051:0~: 38564 2 ;!~ 20 VALVE, "CROSSTYPE" CAMERON "F" GATE 4951.oo SINGLE STRING BLOCK LOG BTM FLGD -.. 10" 5000~P'W/7" OD SEAL SUB PREP - -,- "' AND I/2"'NPT OUTLET FOR 1/8".NPT " ~" CONTROL LINE, W/ONE 4-1/8"BORE " i'4ASTER AND -ONE 4-1/8" BORE St, VAB " ' ~' ~'^ ~'~ S ','Iz*"'n ~" ,~,,.,~ ,,,,,, 5000~,'!P STDD OUTLS. I '~"'' "rnr~ ST " r, ,', ,, ~ , , r, FE ,u, DD L~ .5 BODY STYLE. " i, -, · tNCL 19937 3 HANDWHEE L ' /~.25 6590'12 " GASKET STEEL RING 6-3/8" PD-R239 · 4.29. 248.56 17393 14 1 "7 CA~ XMAS T~,EE FLGD 4"5000~WP THDD = 248.56 4-1/2"EUE ,- .- TOTAL XHAS::'TREE ASSEMBLY : 5930]3!. - . . · · . . .o · e · · · · · · · · · · · · . · · P. O, [iOX 1212 -- HOUSTON, TEXAS 77001 UI{iOH OIL COHPANY OF CALIFORNIA .At~CHORAGE, ALAS}~ . CAS l t~'G D~D£R£D I PROGRAlt - .~'~/2"OD .QUOTE //-9'4474 NATIOI~AL BUTTRESS W/l/8" NPT'CONTROL LINE UNIT PRICE. PART NUMBITR · ~]71 62 1 629.64 7 82J. 4o 7484 4O. . . 18775 8721 ..1 8. 28. 9 DESCRIPTION Loose XYAS TREE MATERIAL · HANGER, TBG ASSEHBLY "DC-FBB" V~/7" OD EXT. SEAL'NECK, 10" 5000~WP X 4"1/2" OD NATIONAL BUTTRESS BTt4 X 4-I/2" EUE TOP ¥t/"H" BPV THD AND IJ8'" LP CONTROL LINE PREP · VALVE,STRAIGHT. NEEDLE 1/2"NPT GAUGE, ASHCROFT PRS~R~ 4-1/2 "FACE 0-5000# RANGE ST/STL CASE~ #1.O2OXT GUN PLAST ! C WRENCH TOTAL LOOSE PACKING, INCL. . XHAS TREE · · · TOTAL LIST PRICES LESS CASH DISCOUNT 2 PER CENT 5TH AND 20TH TOTAL NET PLANT PRICE MATERIAL · PROX. FOB HOUSTON~ ., NOTE-PRICES SH0~ ON THIS VALID FOR 30 DAY'S ONLY. · TEXAS QUOTATION 629. j 28.6~ 666.81i · 6557,1i 1 31.511[ TBUS G-13 (WO) MONTHLY REPORT -2- September 1, 1975 4 8/I7/75 5 8/ 77;5 6 12,01t'TD 11,700'ETD Cmt. Plug 12,011'TD 11,700'ETD Cmt. Plug 12,011'TD I1,700'ETD Gmt. Plug 12,011'TD 11,700'ETD Cmt. Plug liner lap to 2500 psi for 4 hrs. Rev. out. No formation fluid entry. Pooh w/ test tool. Released.rig @ 12:00 Midnite from TBUS G-13 to TBUS G-15 for thru tbg. perf. of G-15 while waiting on frae. equipment. (Footage 0') Recommenced operations on TBUS G-13 @ 12:00 Noon, 8/.15/75. Skidded rig #55 from TBUS G-2 to TBUS G-13. Installed & tested BOPE. Retrieved 9 5/8" RBP @ 950' & 7" RBP @ 11,360'. (Footage 0') RU frac. equipment. Mixed. YF60HC frac. fluid. RIH w/ w/ @EDP to 11,604' Pumped & spotted 23 sx. of 20/40 sd. Allowed sd. to settle. Tagged sd. @ 11,604'. Pooh. RIH w/ 7"'RTTS & set @ 11,249' for frac. treatment. Tested lines & equipment to 8,400 psi. preceded frac. fluid w/ 48 bbls of 12-3 mud acid' followed by 120 bbls of 2% KCL wtr. Frac. well while holding 2500 psi on annulus as follows. Initial rate..- 9 BPM @ 2500 psi. VOLUME SAND CONCENTRATION RATE PRESS. 121 bbls. 0 ~9:iBPM 3800 psi 166 bbls. 1/2#/gal. 11 BPM 3600 psi 120 bbls. l#/gal. 11 BPM 3500 psi 166 bbls. 2#/gal. 11 BPM 3500 psi 166 bbls. 3#/gal. 11 1/2 3200 psi BPM 190 bbls. 4#/gal. 11 1/2 3100 psi BPM (Footage 0') Displ. w/ 2% KCL wtr. Final rate-6 BPM w/ 2875 psi. Total sd. used 76,600#, SI well. Let press, bled into formation. Bled to 900 psi & held. Rev. out & displ, well w/ W@ fluid. RU Schl. & ran GR Log. Tagged sd. bridge @ 11,371'. Ran 6" bit & 7" csg. scraper. CO bridge @ 11,371'. Had sd. fill from 11,397'- ll,700'ETD. Circ. out sd. Pooh. RU Schl. & ran GR Log from 11,700'-11,215'. Logged radioactive frac. material from 11,376'- 11,400' (BenCh #1 perf. from 11,370'-11,400') & from 11,410'-11,446'. (Bench #2 perfs, from 11,410'-11,500'). Total frac. treatment in Benches #1 & #2. RD S chl. (Footage 0') RIH w/ 6" bit & 7" csg. scraper. Circ. btms. up @ ll,.700'ETD, Pooh. Laid dwn. DP & rotary .tools. RU Schl. RIH w/ 7" guage ring & JB to 11,400'. Ran Baker 7" X 4" Model "D" perm. prod. pkr. & set @ ll,300'DIL. RU to run 3 1/2" prod. tbg. BUS 6-13 (WO) IONTHLY REPORT -3- SePtember 1, 1975 8/1~9/75 - 12,011 'TD ll, 700'ETD Cmt. Plug 8/20/75 12,011'TD 11,700'ETD Cmt .Plug l0 8/21/75 11 8/22/75 12 8/23/75 12,01.1'TD 11', 700'ETD Cmt. Plug 12,001'TD ll,700'ETD Cmt. Plug 12,001'TD ll, 700'ETD Cmt. Plug 13 8/24/75 14 8/25/75 12,011'TD ll,700!ETD Cmt. Plug 12; 00 I'TD ll,700'ETD Grot .Plug 15 8/26/75 12,001'TD ll, 700'ETD Cmt. Plug (Footage 0') Completed running 3 1/2" 9.2# N-80 Buttress tbg. Stabbed into pkr. @ 11,300' & tested to 700 psi. Installed ball valve mandrel & spaced out tbg. Installed BPV. Removed BOPD. Installed & tested tree. RU North Star WL. Ran shifting tool & opened XA sleeve @ 11,272'. Shifting tool backed off running tool while Pooh, fell & jammed in Q nipple. @ 11,358'. (Footage 0') Jarred shifting tool free from Q nipple @ 11,358'. Pooh w/ shifting tool. Unable to pull or jar through XA' sleeve @ l! ,.272 " (apparent damage to shifting tool lost in hole). Released shifting tool @ Q nipple @ 11,358'. Ran 2.73"OD guage. Unable to pass XA.sleeve @ 11,272'. Ran 2.695"OD guage. Passed XA sleeve ok. Closed XA @ 11.,272' & tested ok. Reopened XA sleeve._ Ran Go-Int'l. 2.5"OD DP cutter & positioned @ 11,346' in tbg. tail below seal assy. Attempted to cut tbg..@ 11,346'. Cut indicated on collar log. Tbg. tail failed to fall. Recur @ 11,347.5'. Failed to fall. R.'an sinker bars & jars. Jarred-tbg. tail off ok. (Footage 0') Jarred off tbg. tail & Pooh w/ sinker bars & jars. RU & displ. W@ fluid w/ filtered Inlet wtr. Closed XA sleeve @ 11,272'. Put well on gas lift @ 2:00 pm, 8/21/75. (Footage 0') Gas lited & tested well while deactivating Rig. #55. (Footage 0') Gas lifted & tested well while deactiVating Rig #55. 8 hr. prod. test, 8/23/75. GROSS NET: CUT:; FM;:GAS": ~GOR:'GLR'.'' TBG/-CSG~;. 20.887-- ~:~)~i'2"560 "",.', 287 137-'-~ 120 ~960 (Footage 0') Gas lifted & tested well while deactivating Rig #55. (Footage 0') Gas lifted & tested well while deactivating Rigs #55 & #54. 12 hr. prod. test, 8/25/75. GROSS NET CUT FM.GAS GOR GLR TBG/CSG. 2040 1938 5.0% 245 126 1.473 100 940 (Footage 0') Gas lifted & tested well while deactivating Rigs #55 & #54. GROSS NET CUT FM.GAS GOR GLR TBG/CSG. 201~ 19-~2~'~ ~ 500 262 1.514 100 915 TBUS G-13 (WO) MONTHLY REPORT -4- September 1, 1975 16 8/27/75 17 8/28/75 12,001'TD 11,700'ETD Cmt. Plug 12,011'TD 11,700'ETD Cmt. Plug (Footage 0') Continued deactivating Rigs #55 & #54. (Footage 0') Completed deactivating rigs #55 & #54. 6:00 pm, 8/28/75. Released crews @ FINAL REPORT LEASE_ UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE 'NO. TRADING BAY UNIT STATE WELL NO. G-13 FIELD MC-ARTHUR RIVER DATE E. T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS .Tubing Detail Jts. Elevation C,I.W. Hanger 4-1/2" Butt, Tbg, Otis Ball Valve 4-1/2" Butt, Tbg, #1 CX Mandrel 4-1/2" Butt, Tbg, #2 CX Mandrel 4-1/2" Butt, Tbg, #3 CX Mandrel 4-i/2" Butt, Tbg, #4 CX Mandrel 4-1/2" Butt, Tbg, #5 CX Mandrel 4-1/2" Butt. Tbg, #6 CX Mandrel 4-1/2" Butt, Tbg, #7 CX Mandrel 4-1/2" Butt, Tbg, #8 CX Mandrel 4-1/2" Butt, Tbg, #9 CX Mandrel 59 59 39 32 23 18 13 13 12 4-1/2" Butt, Tbg, 80 3-1/2" Butt, x 4-1/2" w/collar 3-1/2" Butt, Tbg, 3 Otis X-Over Mandrel 3-1/2" Butt, Tbg, 1 3-1f2" EUE 8rd x 3-1/2" Butt, w/collar 7" x 3" 29# RHI packer 3-1/.2 "EUE 8rd x 3-1/2" Butt. w/collar Otis X-Nipple 3-1/2" Butt, Tbg, 1 3-1/2" EUE 8rd x 3-1/2" Butt. w/collar Shear Sub 362 38,00 1,00 277,30 3,10 1814,85 6,20 1825,50 6,20 1214,47 6,20 6,20 711,65 6,20 559,25 6,20 406.56 6,20 397.47 6,20 370,73 6.20 2474,13 1,20 93,22 5,7O 31,33 1,10 6,55 1,10 1,20 31,30 1,10 ,70 11321.-61 From -0- 38,00 39,00 316,30 319,40 2134,25 2140,45 3965,95 3972,15 5186,62 5192,82 6190,12 6196,32 6907,97 6914,17 7473,42 7479,62 7886.18 7892,38 8289,85 8296.05 8666,78 8672,98 11147.11 11148,31 11241,53 11247.23 11278,56 112'79,66 11286.21 11287.31 11288,51 11.319,81 11320,91 To 38,00 39,00 316,30 319,40 2134.25 2140,45 3965,95 3972.15 5186,62 5192,82 6190.12 6196,32 6907.97 6914,17 7473,42 7479,62 7886,18 7892.38 8289,85 8296,05 8666,78 8672,98 11147,11 11148,31 11241.53 11247,23 11278,56 11279.66 11286,21 11287.31 11288.51 11319.81 11320.91 11321,61 . LEASE UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D · PAGE NO.L TRADING BAY UNIT STATE I~ELL NO. G-13 FIELD MC ARTHUR RIVER DATE 9/29/68 through 10/1168 . 4 10 E. T. D. 12011' 12011' 12011' 11954' ETD DETAILS (~f OPERATIONS, DES~;RIPTIONS & RESULTS Repaired A.C. "skid. Drld out floats & cmt. Increased salinity of mud to 29,000 ppm, Drld & surveyed 8-1/2" hole from 11,407' to 12,011. Conditioned hole for electric logs. Schlumberger ran electric logs. Schlumberger ran DIL, S. P., LL3, bILL, Sonic HRD - Density. Had to change out Schlumberger Line before running hrd. R.I.H, to condition for 7" Inr. P.O,H. Made up 7" lnr w/BOT hanger. R.I.H, w/sa~e set @ 12,000'. Cmt w/300 sx CFR-2, preceded w/50 ft 3 Caustic wtr. Bumped plug w/2600#, floats held O.K. P.O,H. C,I.P. @ 3:15 PM 10/3/68. 7" Liner Detail Jts. -- 7" Baker "G" Shoe 7" 29# N-80 Butt., R-3 New, SI~S B.O.T. Landing Collar 7" 29# N-80 Butt., R-3 New, Sb~S 7" x 9-5/8" B.O.T. Liner Hanger 17 18 2.35 11997.65 - 12000.00 42.13 11955.52 - 11997.65 .86 11954,66 - 11955.52 711.72 11242.94 - 11954.66 23,13 11219.81 - 11242.94 753.85 Picked up 3-1/2" Drill Pipe. ~.I.H. w/bit, fnd top cmt @ 10775'. Drld firm cmt fro~ 10755' to 11220' (top liner hanger). Circ hole clean. P.O.H. Pick up 6" bit & 7" csg crap~r. Tstd !nr lap w/2,400~~ for 20 min. - no decrease. R.I,H. w/6". bit & 7" csg scraper. Dfld cmt from 11220' to 11228'. R.I.H. to 11900'. Drld cmt 11,900' to I1,,~54'. Circ. hole clean. Disp mud w/wtr, w~r w/diesel. P.O.H, Laid do,~ 3-1/2" drill pipe, removed drill pipe rubbers, R.U. Schlumberger. Ran CBL indicated poor bonding throughout. R.D. Schlumberger. R,U. & rah 3-1/2" & 4-1/2" tbg @ 1i,322' w/Guiberson'RHI pkr @ 11,287' (See Detail). Set pkr & sheared trip sub w/3000#. Tstd pkr w/2,500# - O.K. Set Ca~eron tree &tsted to 5,000# - O.K., R.U. Schlumberger perf. Perforated 4 H/FT w/2" Scallop Gun: 11770'-11740', 11720'-11520', 11.500'- 1i410' 11400'-11370' Pressure increased to 20Of/ while perforating. R.D. Schlumberger. RIG RELEASED 6:00 AM 10/6/68, Prep to move to G-15. Open sleeve above top pkr. Depress diesel out of tbg w/nitrogen. Closed sleeve. Blew well UNION OIL co. Of CALIFORNIA SHEET D DRILLING RECORD Page NO., _ LEASE TRADING BAY UNIT STATE SVELL NO., G-!3 FIELD MC ARTHUR RIVER DATE 9/4/68 5 through 11 12 13 14 15 16 17 through 19 2O through 24 25 28 E.T.D. DETAILS Of OPERATIONS, DESCRIPTIONS & RESULTS 5670' Ran bit #11 w/junk sub, had some junk on bottom. Worked by same, drilled 12-1/4" hole to 5670'. Recovered most of junk w/junk sub. 9247' Drld & surveyed 12-1/4" hole from 5670' to 9247'. 9435' Drld to 9435'. P.O.H, R.I..w/Dyna Drill for left hand turn. Had difficulty orienting. 9606' Unable to orient Dyna Drill'. P.O.H, R.I, w/drlg assby. Drld 9435' to 9606'. P.O.H, R.I.H. w/ Dyna Drill. Dyna Drilled from 9606' to 9678'. Survey indicated hole to be turning 90~ lef? 9200' Ran in hole w/limber drlg assby. Pushed around Dyna Drill run & continued drlg~to 9796'. SurVey indicated hole had turned severely to the right Re-ra? Survey,.no change'. Dr!d to 9832' & re-ran survey with same results. ;.O.H. Ran open ended drill pipe to 9400'. Cmtd w/300 sx Class "G" w/l% CFR-2. C.I.P. @ I1:00 AM 9-15~65. RIH w/drlg assby, tagged top of cmt @ 9171'. Polished plug to 9200'. P.O,H. for Dyna Drill to jump plug, 9261' Dyna Drilled from'9200' '~o 92,40~. P.O.H. for bit change. Re-ran Dyna Drill. & drld fro~ 9240-9261', R.I.H. w/limber drlg. assby, Reamed Dyna Drill run & drld to 9372'. P.O.H, R,I.H, w/locked in assembly. Drld & surveyed 12-1/4" hole from 9372' to 9840' 9954' Shut down Rig for 8-1/2 hfs for electCical panel change. Cont drlg 12-1/4" hole to 9954', Drld & surveyed 12-1/4" hole from 9954' to 11120', having some excessive 11120~* torque while drlg - not much hole drag on trips, 11407' Drld & surveyed !2-1/4" hole from 11120 to 11407'. Schlumberger ran DIL, FDC-GR, Contitioned hole for 9-5/8" csg, Ran & cmtd 281 joints 9-5/8" csg, (See Detail). Cmted through shoe with I100 sx Clas~ "G" w/l% CFR-2, Bumped · plug w/1600 psi. Released' pressure. Floats held O.K. C,I.P. 1:45 9/28/68 Nipp!ed do~, set 9-5/8" slips, cut off 9-5/8" installed & tstd tbg head & nipp!ed up, Head tested-w/3000 psi O.K, 9-5/8" Casing Detail Jts. 9-5/8" Float Shoe 1.98 11347.55 - 11349.53 9-5/8" 47# P-110 Butt· Csg. 1 42.60 11304.95 - 11347.55 9-5/8" Float Collar 1.70 11303.25 - 11304.95 9-5/8" 47# P-110 Butt. Csg. 1 41.6'5 11261.60 ~ 11303,25 9-5/8" Self-fill Diff. Collar 2.12 11259.48'- 11261.60 9-5/8" 47# P-l!0 Butt. C~g. 71 2863.64 8395.84 - i1259~48 9-5/8".47# N-80 Butt. Csg. 44 1688.27 6707.57 - 8395,84 9-5/8" 43.5# N-80 Butt.-Csg, 34 1411,87 5295.70 - 6707,57 . ,, 9-5/8" 40# N-80 Butt. Csg, 129 5220.90 74.80 5295.70 9-5/8" 47# N-80 Butt. Csg. 1 38.80 36.00 74.80 . Landed Below Zero ........ $~.0q '--0-- 36'00 ,: 281 11349.53 "~ Tested blind rams w/!500 psi for. 20 min. - O,K. R.I.H. tagged top of cmt @ 1t~252'.. Tstd pipe rams w/1500 psi for 10 min, - O.K. Tstd Hydril w/1000 · Psi for 10 min. O,K Due to loss of A C power, shut down rio UNION OIL CO. OF CALIFORNIA DRILLING RECORD LEASE TRADING BAY L~IT STATE VV-ELL NO .... G- 13 SHEET D PAGE No., FIELD. MC ARTHUR RIVER DATE E.T.D. .DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8/23/68 24 25 26 27 620' 620' 1521' 3003' 28 29 3O 31 ~/:i./68 ",. 3 4210' 4735' 5125' 5125' 5125' 5125' 5125' _ .. Started moving Rig from G-7 at 10:00 ~M. Shut do~m '6-1/2 hrs because of electrical power failure. SPUDDED: 3:30 AM -(8-24-68). Drilling on Junk. Ran Globe Basket 2 runs, recovered 10 gallons of boulders. Dr!d 15" hole to 620'. RIH w/22" Servco Expanding Hole Opener. Opened 15" hole to 22" to 620'. RIH w/18" cond. mill. Circ, clean. Ran 15 jts 17-3/4" csg, .312" wall, spiral weld, slip joint set @ 602' w/ Howco Dup!es Shoe @ 602'. C'emented w/750 sx 2% CaCl2 (last 50 sx 4% CaC12) Cement circulated. Held csg for 2-1/2 hrs. Cut off & nipple up 20." Hydri1] WOC a total 18 hrs. RIH & drld 15" hole to 797'. POH & picked up 7-3/4" Dynadriil. Orient & Dyna.drilled to 1085'. POH. to change Drill Assembly. RIH & drld to 1521'. Dr.~led and surveyed to 3003', Twisted off, found galled and jumped thread 8 joints drill pipe down. RI w/overshot with 6-1/4" grapple. Could not get over fish. RI w/Il" O.S. with 6-1/4" grapple, engaged fish, pulled 200,000#, weight dropped to 40,000#. POH leaving 8 joints H.W. pipe, 6 D.C.'s ~n hole. R!H w/O.S., engaged fish, pulled loose. RIH to drill, backed off, dropped 4 D.C., 2 moneis.. RIH, screwed into fish. POH. RIH checking each tool joint. Drilled and surveyed to.4210'. Drilled to 4340'. POH. RI w/Dyna drill-to set for left hand turn, Dyna drilled from 4340' to 4451'. POH, RI w/a~sembly to follow Dyna Drill run. Dr!d to 4735' w/same. POH to P.U. locked assembly. Drld to 5125'. P.U. 17" conv hole opener. Opened hole from 600' to 2451',- Opened 12-1/4" hole to 17" to 4685'. Opened hole to 5125'. Lost leg assembly on 17" hole opener @ 4690'. Finished hole with 16" hole opener. Location of leg, roller and cutter unknown. Made short trip, circ bottoms up, ran 137 joints 61# J-55 13-3/8" seal lock csg. Hung shoe @ 5115'. (See Casing Detail). 13-3/8 CasiD~%_De tail Howco Float Shoe 1 jt 61# J-55 13-3/8" buttress Howco Self Fill Collar Buttress × Seal Lock X-Over 136 its 61# J-55 13-3/8".Seal Lock Landed Below Zero 2.00 39.16 2.00 1.50 5027.74 42.60 '5115.00 5113.00 - 5115.00 5073.84 - 5113.00 5071.84 - 5073~84 5070.34 - 5071.84 42.60 - 5070.34 --0-- Cemented above w/1690 sx Class "G" plus 10% Dicel plus 6% Gel plus 1% D-31 followed by 200 sx. Class "G". Full re~urns, cement ~0 surface. ~C~I.P. @ 1:30 AM. Float failed, held 500 psi until 6:00 AM. .Released pressure, cut off csg. installed 13-3/8" x 12" Series 900 Shaffer KD head. Tested to 3000 psi for 15 min. - O.K. Installed Riser & B.O.P.E. R.I.H. w/drlg assembly. Drld cmt, collar, shoe. C.O. to bottom, encountered junk. P.O. Ho P.U. flat bottom mill. Milled on junk. Ran Globe Junk Basket, no recovery Ran bit & ', ' ' '~, .. jun~ sub, ~r~,~ed on j~nk from 5131' ~o 5158'. ~ecovered junk sub full of' iron. [ _-:_ I ' ' ' ' ' :' -' .~:- ': - '- "--. ' - -- DRILLING RECORD PAGE NO. n .AS . S rA? FIELD MC ARTHUR ' Leg 4, I831"N & 1493'W from SE corner SeCtion 29, T9N, R13W, SM. PERMIT NO, 68-57 T.D. I2UIi DEVIATION (B.H.L.) COMPANY ENGINEER SPUD DATE 8 / 24 / 68 COMP. DATE CONTRACTOR W0D EGO TYPE UNIT National 1320 UE 10/6/68 DRILL PIPE DESCRIPTION 5" Hughes X hole ELEVATIONS: WATER DEPTH 1 zS. 00 SERIAL NO. ADL-17594 Pu T. TO OCEAN FLOOR 235.60 [ R' T' TO MLLW 110' 60 T'V'D' R'T' TO DRILL DECK 19' 30 R' T' TO APPROVED: ~' 42.60 BlT RECORD Ifiz "'i ' ' VEL. DEPTH & DEVIATION BlT . JET DEPTH VERTICAL · DATE DEPTH NO. SIZE MAKE TYPE SIZE OUT FEET HOURS ANN. T ..DIRECTIONAL · 8/23/68 352 1RR 15" Reed ST3A 3-1/2 ' 383 31 1-1/2 - - Drill on boulders .' .....24 365 1RR 15" " " '" 416 51 1 _ _ T""3. B-1 ~--' ' 24 416 2 1~". Globe SiS3A.. 3-16 624 ? 08 .~ i . Tgl B-1 " 24 '" 624 HO1 22" Servco Exp. - 624 267 4.. . T-2 B-2. [ 26 620 2RR 15" Globe. SS3A ,3-16 797 177 4 73 310 T-2 B-1 I! I! "' 27 797 3 12-1/4 Reed YT3A 2~t5_1/l~. 1672 ggl !O ?~ .~ln. .. 27 1678 4 12-1/4 Globe S$T3 3/13 3003 1395 ID 115 /~85 T.-4 B-2 28 3003 5 12-1/4 Globe SST3 3/13 43&fl 1~37 ]3-],/? 105 650 T-4 B-3 :_ 29 4340 6 12-1/4 Reed YTIAG 3-12 4'451 ]]1 5-117 1~ A~a n .... a~-, T;4 B-3 · 30 4451 7 12-1/4 Globe MT3G 3-1,3 A735 284 4 105 f~50 Pul]e~ for ~ '30...... 4735 8 12-174 Smith DGHJ 3-13' 5125~ 390 5-1/2 105 45~ Csg Point ... 31 600 HO2 17 Smith CONV. - 3754 3154 16-1/2 57 - T-~ B-4 31 '' 3754 HO3 i7 Smith CO~' - 4690 946 12-1/2 '57 - Lost Leg Assembly "9/i/68 4690 HO4 16 " " - 5125 435 8-1/2'" .5..7 - T-2 B-.4 2 5125 t 9 1221/4 HTC OSC1G 3-14 5125 .... Junk in hole .I 3 5 ! ~ 5 M!L[12-1./4 Servco FLAT - 5131 2 1/2I'[ blill on ,Junk ....... ' 3 ' 5131 10 12-1/4 HTC OSC!G ~.-1/2Bl~; 5162 31 5 Drill on junk ~. 4 5162 11 12-1/4 Smith DCH 3-14 5492 330 8-1/2 114 , 412' T-3 Bfl2 4 I 5492 12 12-1/4 Reed YT3A 3-14 5920 428 11 114 '412 T-4 B-2 _ 5 ] 5920 13 12-1/4 Globe !ST3G " 6570 650 9-1/2 " " T-3 B-2 · . _ 5 6570 14 "- " " ' " 7015 445 8_1/2 " " Pulled for AC Power _ 6 7015 15 " " " " 7237 222 5 " "' T-3 B-2--' _ 7 7237 16 " Smith K2HfJ " 7477 240 8 '" " Tr4 B-3 _ 7 .7477 17 " HTC OSC!G " 7693 216 7-1/2 " " T-4 B-2 ,. ~ 8 7693 !8 " GlObe ST3G 3-15 7902 209 6-1/2 " 358 T-3 B-2 _ 8 7902 ..19 " " MT3G " 8218 316 9-1/2 " " T-3. B-2 9 8218 20 " Globe· " " 8443 225 7-J./2 " " T-3 B-2 _ 10 8443 21 " SEC S4TG " 8644 201 8 6' ,, ,, ,, 10 .8644 22 " Reed YT1AG " · 8799 155 7-1/2 " " " " _ 11 8799 23 " Globe ST3G " 9037 238 10-1/2 " "' " "' _ 11 9037 24 ,, ,, ,, ,i 9247 210 6-1/2 " 360 ~'-4 ~'-3 , _ 12 9247 25 " smith DGH-J " 9435 188 12 '" " T-3 B-3 12 9435 26 " Reed ST1AG 3~24 9435 " 0 Unabl~ to c.rient Dy~ladrill 13 9435 27 ,' Globe bfr3G 3-15 ' 9606 171 7-1/2 114 360 T~-2,. B.-2 -- 13 9606 26Rt~ "' Reed ST1AG 3-24 9678 72 6 98 - Dynadri!led T-3 B-2 -" 14 9678 28 " Globe ST3G 3-15 9832 154 9-1/2 114 360 . , __ 15 29 " Reed YT1AG " 9200 Plt.g Back - Po] ish Cement Plug 16 9200 30 " " ST1AG 3-24 i 9240 40 6-172 105 360 Dynadrilled T-4 B-3 ,.. '_ 16 9240 31 " " " " 9261 21 7 10.5 " " '17 9261 29RR " " " 3-15 9372 111 5-1/2 114 " T-2.. B-2 , ., 18 .9372 32 " Globe ST3G " 9684 312 11-1/2 " " " " 18. 9684 33 " " " " 9840 156. 9 " " P. ulled for Shut Do~m 19 9840 34 " " " " 10013 173 10 1.10 ~46 T-2 B-2 20 10013 35 " " " " - 10128 115 9-,1/2 " " T-3 B-3 'f21 10].28 36 " " MT3G " 10298 170 7-1/2 110 '" T-3 B-2 . .;21 10298 37 ,, Smith K2H I ,, - 10464 '166 8-1/2 ,, ,, T_3 B-3 '" ~i 23 ~0464 38 " Globe. MT3G " 10672 208 10 " '" " " _ 2'3 10672 39 " Smith K2H " 10800 128 7-1/2 " " T-3 B-2 1/4" O.G. 23 10800 40 " GlObe MT3G " 10901 ]~01 5 " " T-4 B-2' '1/4" O.G. _ 24 10901 41 " RTC 0DV " 11043 142 8-1/2 " " T-3 B-2 . 24 110_..4.3 42 " " " ' " 11226 183 9 " " G-3 Gradin~ in ei.~hts -25 11226 43 " ' ." '" "' 11331 105 11 " " G-3 26 11331 44 "' . Globe ST'3G- " 11407 - 76 .. 4 " ,, T-4 B-2 _ 27 11407:29Rg, " Reed YT1AG " Conditioned imle f~ 9-.5/~'" 28 .114.0..7 45' 8-1/2 . HTC XDR' 3-12 1.1495 88 5-1/2 ].75 338 · 29 ' 11495 46 ..". .. " X55R " 11791 296 IS-l/2 " " T-8 B-8 O.G. 1/8" 30' .1.1791 47 "' " XDR "' 11872 81 7 " " T-7 B-2 10/!/68 1187~'- 48 " " " " 11936 64 [' ~ I '1' ' ' ...... -- I ' 2".. i1936 i 49: ' :' ' Reed '' S ' ' ' ' 12011 65 3 ' I" T-4 g.-2 ~- 1 ,:, fr ,i UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO.__ 1 -A LEASE_ Trading Bay Unit State DATE 2/2/69 2/3/69 2/8169 219/69 E. T. D. WELL NO. G-13 FIELD' blcArthur River DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Upon initial completion, G-13 failed to flow. Gas lift equipment was installed, and an unsuccessful attempt made to produce the well. Producing characteristics indicated very little fluid entry existed into the wellbore. The tlemlock Zone was thru-tubing reperforated to improve productivity. Rig Released from G-17 @ 6:00 PM 2/2/69. Move to G-13 for repair. Remove ball valve & gas lift valves, depressed fluid to 3950' w/gas. 'RU Schlumberger to reperforate Hemlock Oil Zone. Reperforated 4 hpf w/2" scallop gun: 11770-11740; 11720-11520; 11500-11410; 11400-11370 No increase in pressure. RD Schlumberger. Reinstalled gas lift vaIVes.& ball valve. Prep to return well to production on gas lift RIG RELEASED @ 10:30 AM 2/3/69. '.. 636/350 45.0 Cut, 825 CP, 175 TP, 180 choke, 295 GOR - gas lift -- 708/488 31.0 Cut., 24.2 gravity, 825 CP, 200 TP, 180 choke - product,.on, well cleaning up. RECEIVED FEB 1 7 1969 DI¥I$10N OF OIL AND OAS ANCHOi~/-.~E LEASE, DATE 9/13/69 o 14 16 17 18 19 UNION ' ' KLV OIL CO. OF CALIFORI tI . DRILLING RECORD REL WORK OVER Trading Bay Unit State SHEET D "PAGE NO. 1 W.~ FI~ ... G-13 ' ~ELD . McArihur River WELL NO. DETAILS OF OPERATIONS, DESCRIPTIONS 8: RESULTS : i , . , E. T. D. 11,954' 11,413' 11,700' 11,700' 11,700'. Moved rig over Conductor. Tied into tbg and killed well with 65#/ft3 Baroid Invermul oil base mud. ND Xmas tree & NU BOP's. Instld drip pans & special mud equipment for oil bas .'mud use. Pulled Hydraulic pkr free & POll with tbg. Instld mud p~ns under RT, lengthened bell nipple. RIH with 3-1/2" dp, open ended. Circ & conditioned Invermul. Conditioned Invermul. Lay cmt plug with 100 sx Class "G" with 1% CFR-2 from 11,413' - 11,954' to cover btm Interval of Hemlock Zone presumed to be wet. Cmt Slurry was preceded and followed by 25 ft3 wtr & 25 ft3 diesel to prevent contamination. WOC 11 hrs. D~ld hard cmt from 11,413' - 11,700'. Left cement across old perforations at 11,740' - 11,770'. Schlum perfd 11,370' - 11,400', 11,410' - 11,500', 11,520' - 11,660' with 4 csg jets per ft. Ran 362 its (il,205') 4-1/2" & 3-1/2" tbg @ 11,318.91' with 7" Guiberson RE-1 pkr @ 11283.51' and with gas lift valves in place. Landed in tbg head, ND EOE & instld single Xmas Tree. Tested tree w/5000# OK. Displaced wi~x diesel down tbg & around pkr. Dropped pkr setting ball and set pkr. Released Rig to well G-2 @ 7:00 PM 9/18/69. 4-1/2" & 3-1/2" Tubing Detail Guiberson Shear Sub 1 jt 3-1/2" 9.2# N-80 butt t6g. Otis Type X Landing Nipple 3-1/2" butt. x 3-1/8" EUE X-O Guiberson 7" x 3-1/2" Eydraulic pkr 3-1/2" butt. x 3-1/2" EUE X-0 1 jt 3-1/2" 9.2# N-80 butt tbg Otis ~ype X Sliding Sleeve 3 jts 3-1/2" 9.2# N-80 butt tbg 4-1/2" butt. x 3-1/2" butt. XO 80 j ts 4-1/2" butt. tbg 12.6# I<-80 Otis Type CX Mandrel 12 j ts 4-1/2" 12.6# N-80 butt. tbg. Otis CX b~ndrel 13 its 4-1/2" butt. tbg. 12.6# N-80 Otis CX Mandrel 13 j ts 4-1/2" i2.6# N-80 butt. t'bg. Otis CX Mandrel , ~ 18 j ts 4-1/2" 12,6# N-80 butt. tbg, Otis CX Mandrel. 23 jts 4-1/2" 12,6# ~-80 butt. tbg. Otis CX Mandrel 32 jts 4-1/2" 12.6# N-80 butt..tbg. Otis CX i-~andrel 39 j ts 4-1/2" butt. tbg. 12.6# N-80 Otis CX Mandrel 59 j ts 4-1/2" 12,6# N-80 butt. tbg. -. 0tis CX-Mandrel 59 jts 4-1/2" 12.6# N-80 butt. tbg. Otis Ball Valve Landing Nzpt le 9 jts 4-1/2" 12,6# ~;-80 butt. tbg. Cameron Tubing Hanger Below KDB ~3n~th Bottom ~ 11318.91 11318.21 .7O 31.30 1.20 1.10 6.55 1.10 31.33 3.00 93.22 1.20 2474.13 6.20 370.73 · 6.20 397.47 6.20 406.56' 6.20~ 559.25 6.20 711.65 6.20 997.30 6.20' 1214.47 6.20 1825.50 6.20 1814.85 3.10 277.30 1.00 38.00 11283.51 11244.53 11148.31 8672.98 8296.05 7892.38 7479.62 6914.17 6196.32 5192.82 3972.15 2140,45 319.40 -,oo,-^ !'-, iUNiON'-/C)ji! , CO. OF CALIFORNIA ,tm D ¢!. C j~REPAIR RECORD . :t3~:._~75 COMPLETED' ~MIT NO.~~ SERIAL ~m~,~ C,~}ve~~ CASING & TUBING RECORD 'IZE- -31:8 ~ '5/8" SHEET A PAGE NO. CONTRACTOR ..... _P_a_r_ke_r_..D_r_!g, Co, ...... TY P E U N Itl'.'. ..... 132_0__U '_E_I21ation a ]. ELEVATIONS: GROUND See CASING HEAD. P_rioJc__ TUBING ttEAD J-jj_~.tory __ ROTARY DRIVE BUSHING -~r REMARKS PEPT~ ,F Y.~?~.2~!.',__[ ~__~ AD_~ ~- 602' ~ ..~]~2 ¢~lllSpiral Cmt'd w./ 750 sx. Class "G" w/ 2% CaC12. Last 50 sx. 4% ~ [ CaC12. Circ-good returns. 5115' il 61~ [ J-55 , (Seatlo~k) See original Well History for details. (9/2/68) 11,350~];40,47,43.5~ Pll0,N8~ See original Well History for details. (9/25/68) 12,00(i~ 29~ [ N-80 ~ (B~t~ess) See original Well History foe details. Cmt. w/ 300 '[ t. ~ ' sx. CFR-2. /10/3/68) a' ~ ~ ,,,.- .... ~/6168 I N_'T_I~R V AL 11,740"11,770' 1t, 52;0'-11, 720' 11,4Ii0'- 11,500' 11,400'-11,370' E.T,D.___ '11,954 .NET OIL, 1952 ~/28/7 Pre~duc'.l.~.on I¢ PRESENT CONDITION Open for production. Perf. 4 hpf w/ 2" Scallop Gun. 1! !1 II Il Ii II II II It It tt II Il II II I! I! II i~ I! 11 11 11 II II I1 II . 11,370'-11,400' 11,410'-11,500' 1t, 520'-11,720' 1'1,740'-11,770' Bench #1 (Hemlock) Bench #2 (Hemlock) Bench #3 (Hemlock) Bench #4 (Hemlock) 960 120 [ 560 WELL HISTORY PRIOR TO REPAIR _ _OOR .................. 287 LAST COMPLETION NO. 1 DMPLETION DATE: 10/10/68 RODUCING YNTERVAL:_ them lodc_B_c_nchr2x_.,~L_JLg~[~-.~;Z.._ .See-abou-e. qlTIAL PRODUCTION:__._ 208.8 Grosn, !952-~NcL. AST REGULAR PROD. & DATE: __2ul_y_tl-,--l-gZ5= ~IM JLATIVE PfAC:~)UC I tON:__ J uIL3J. EASON FOF. REP,~Hu · · · · · Form D-IOO1-B UNiOl l OIL CO. Of CALIFOI NIA REPAIR RECORD SHEET B PAGE NO ..... 2 ~, .EASE TRADING BAY UNIT STATE ~.OMPLETION DATE: ...... 8 / 2 8 /25____ , ' ! i DATE WELL No.G-13 WOFIELD .... McARTHUR RIVER FIELD APPROVED Jim R. C'allenaer Shaffer / Cam eton iii il i, A ..... i~ i ~ i DET ILS OF oPE IONS, DESCRIPTIONS & RESULTS i iii W~LL Iq]~AD 'ASSEMBLY ' ]ASING HEAD:. Shaffer KD 12" 900 series X 13 3/8" SOW 2ASING HANGER: Shaffer 12" Nominal - 9 5/8" Model KD KS ~ASING SPOOL: ?UBING HEAD:. ~ I C_,.'uneron:DC=B_7_12 _12" 3000# X 10" 5000# w/ 5000# studded outlet. .?UBING HANGER: DC-FBB 10" nominal 4 1/2" buttress btm. X 4 1/2" EUE top. 'UBING ItEADTOP: _.55mgle strin[; solid block_lgg typ~._C_ameron :btm. flangetoI 5000~ W/7" pocket. /[ASTER VALVES: :HRISTMAS TREE TOP CONN.:_ 4 ]./2 EUE UNI( N 'Oil CO-. Of califo rNia MUD RECORD SHEET B pAGE NO.., LEASE T.RA,, l~G BAY UNIT STATE TYPE WELL NO. G-lB FIELD MC ARTHUR RIVER DISTRIBUTOR IMC 8/24/6 soo so o.s i'i/: ~" 2> '" 620 76 42 7.2 9.0 1 Ran 17-3/4" csg. 26 671 75 43 9.0 10.0 200PPM~ 0 1 11 "' 27 1678 78 38 7,7 9.0 200 0 1/2 8 , ' 28 ~ 3003 79. 43 7.2 9.0 200 0 1 8 .... . - 29 4000 80 44 5.4 9;0 200 0 1 11 ., 30 4685 80 42 5.1 9.7 200 0 1 11 ,, 3i 5i25 8i 44 .5.0 9.5 200 0 · i ii ' ~/6'8 512.5 80 47 5.0 9.5~ 200 0 3/4 12 open hole 12-1/4" - 17", run 13~3/ . 2 5125 .... ' .... WOC -3 5125 78 43 5,9 10,0 i00 0 1/4 12 Cutttns weight.., w/wtr, desilter . .... 4 51.62 73 50 5.4 9,8 200 2 3/4 8 Converting tq sart base . 5 5764 7i 40 5,7 9,0 700 2 1/4 7 Using Inlet water 6 6666 74 49 5.7 9,8 900 6 1 6 7 7358 72.5 58 5~8 9.8 900 6 1-3/z 12 Lost AC Generator. no mix .... · 8 7693 73 44 5.4 1.0.5 1100 7 1. 9 -- 9 8210 73.5 ~ 5.0 10.6 11.000 7 1. 9 l.O 8595 74 47 5.1 10.5 11000 7 3/A ~2 1~ 8830 73.5 . 46 5.2 iO.O ~10~0 7 3/4 12 12 9247 72 &5 5.1 lO_O 11000 ~ 7 ~/4 14 9630 72 AS 5,0 10.2 10000 8 1/4 13 Dynadrillad - h~lo caving 15 97q0 73 1,8 5 0 9 8 q50O 7 1/0 13 - .. . , - . . j ~ 16 9195 72 47 ~.A t0.0 9500 8 1/4 13 Pl,g gnck -Polt~had Plug 17 g?~O 73 &7 A.O ~ ! !ODD0 9 1/4 12 Dy~ctr~ 1 ! 19 9807 7S '49 4.0 ~0.6 !1000 9 1-3/z 20 ~00~3 72 /,4 4,3 ]0,6 1In00' 7 3/~ 8 ?? 10579 73 4q A.3 !0~3 ]1000 ~ !/2 . 2g lOqn! 72 48 4,2 10_5 1 ].OOO 7 1/4'. ?~ !1.]?0 71 .~ ~g A~3 !O:a 'iOnO 6 l/? 9 ?I 5 71 50 /+;~ q:6 ll0O0 7 I/2 1! 26 11326 72 49 4 0 10,2 10000 7 1/2 1.2 .. 27 . 11~7 72 55 J ~.8 10.7 10000 8 1/2 12 Ran 9-5/8" c.sg. . 28 11407 72 63 5,0 10,3 10500 8 1/4 12 Camented 9-5/8" csg. 29 I~420 72 45 5 3 10.2~2~000' 7 1/4 ~_ 30 1.!~20 7~ ~8 ~.6 i0.8 [26000 8 1/2 ~.~ 10/1/6~ 11865 75 50 4,6 11.0 26000 8 1/4 1_2 2 120].!. 75 ~6 4.3 10.8 27000. 8 1/4 1.0 T.,D,. COndition hole for logs 3 1.201! 75 45 h.2 10.8 27000 8 I,/4 l0 Condition hole for 7" liner . . _. . '. . . . ,,- , , . c · . .... . . . '' ~ , . _ [ - . · . . . , . . ~ . . ,, .... , , .- .... . . ~ ~ : . . ' _ t ' . [. REPORT and P~N of SUB-SURFACE SURVEY UNION OIL COMPANY T. RU. ~-13 COOK INLE'[, ALASKA JOB NO.~ ~).~?~. OCTOBER 1968 DRILLING CONTROL CORPORATION LONG BEACH, CALIFOR~A DRILLING CONTROL CORP. s,,:,:T NO. BUIkVIgY DATA SHEET COMPANY. Union Oi% Cc~p~,.sny , ., DATE_ October 1968 JOB NO .... WELL_ Grayling ~ 13 · FIELD C~k It~]~.~_ COUNTY STATE. Alaska .... TRUE R~ANGULAR COORDINATES MEASURED DRIFT DEVIATION DRIFT VERTICAL COURSE DI~ON ...... REMA~ DEPTH ANGLE DEPTH NORTH SOUTH EAST WEST . , , , , ... . 797 797 00 ASS~ VE, RTIC3 L TO T. ~IS ~OINT 822 1 o 15' 821 99 55 S 60° W 28 48 884 3° 30' 883 87 3 79 N 60° W 1 62 3 76 947 6° 30' 946 47 7 13 N 74° W 3 59 10 61 1010 9° 00' 1008 68 9 86 N 81© W 5: ]_3 20 35 1303 18° 00' 1287 36 90 54 N 890 W 61 71 110 87 1646. 3'1° 00' ].581 38 176 65 N 87° W 15! 95 287 27 2016 32© 45' 1892 55 200 ].7 N 84° W 36 87 4~6 34 2548 33° '00~ 2338 74 289 73. N 83° W 72 19 773 90 3167 33° 00' 2857 90 , 337 11 N 82° W 119 12 1107 74 3807~ 33© 00' 3394 67 348 54 N 78° W 191 58 1448 65 4340 3].° 30' 3849 11 278 49 ! N 75° W 263 65 ' 1717~64 4383 31° 30' 3885 77 22 47 N 85° W 265 61 1740 02 4641 36~ 30' 4093 18 153 46 ,N 88o W 270 97 , i893 39 5135 38° 15~ 4481 12 305 84 N 86° W' 292 32 I 2198 50 5492 37° 15~ 4765 29 216 09 N 84° W 314 90 2413 40 5920 ,35° ~5' 5112 65 250 04 N 83° W 345 38 266]. 56 ~ 30' 6570 3~° 5628 36 395 72 N 81° W 407 27 3052 41 7015 39° 00' 5974 17 280 04 N 78° W 465 49 3326 7237 38~ 00' 6149 11 136 69 N 77° W 496 25 3459 5]_ , · 7477 36° ~5~ 6341 42 143 59 N 76° W 530 98 3598 7693 36° 30~ 6515 06 128 48 N 73° W 568 55 3721 71 7902 36° 00' 6684 14 122. 85 N 72© W 606 51 3~38 55 8218 36° 15' 6938 96 186 85 b? 70° W . 670 4]. 4014 13 8443 ~ 36© 15' ~ 7120 40 133 04 N 69° W 718 09 . 4138 34 ............. DRILLING CONTROL CORP. S.E£T NO. flU~VEY DATA COMPANY Union Oil Ccr~o. anv DATE Ck~.~.~r ]96~ , JOB NO .... ~ ' c # 13 Cook /nlet STATE WE L L ~raylln~ F I ELD COUNTY TRUE DEVIATION D~]FT RZCTANGU]~R COORD]NA'IT, S NIEASURED DR]TI' VEfil']CA~ DEPTH ANGLE COUBSE D~ON ~ DEPTH NORTH SOUTH EAST WEST ,, , ,., 8644 57° 0~~ 7280 92 120 96 N 67° W 7¢5 35 4249 68 8799 56° 45' 7405 12 92 '14 N 61° W 810 31 43~0 79 9037 33° ~5' 7603 02 132 23 N 61° ~ 874 42 44~6 9200 33° 00 77~9 73 8P 77 N 61© ~ 917 4~ 4524 . ~. 9307 35° ~5~ 7827 11 61 75 N,67° ~ 941 59 45~0 92 9367 39° 00' 7873 74 37 76 N 67° W 956 34 46].5 6~ 9684 39° 00' 8120 08 199 49 N 65° W .1040 64 4796 9840 38° 00' 8~43 01 96 05 N 63° W 1084 25 4S~2 10,013 36° 45' 8381 63 103 51 N 60° W 1136 01 4971 70 10,128 35° 45' 8474 96 67 18 N 60° W 1i6~ 60 5029 10,298 37° 00~ 8610 72 102 31 N 57° W 1225 32 5115 69 10,464 39° 30' 8739 81 105 59 N 53° W 1288 86 ~20~ 10,672 39° 30~ 9899 30 132 31 N 52° W 1370 32 5304 27 . 10,800 38° 15' 9999 82 79 124 N 48~ W 1423 34 536~ 15 ~ 10,901 37° 30" ~079 95 61 49 N 49~ W 1463168 5409 56 11,043 37° 00' 9193 35 85 46 N 5].° W 1517 46 5475 11,226 35° 00' 9343 26 ~' 104 97 .N 48° W 1587 70 555'3 97 11,331 34° 30, 9429 79 .59 47 N 5].° W 1625 12 5~00 11,407 34° 45' 9492 24 43 32 N 51° W 1652 38 5633 11,494 3~° 30' 9562. 18 51 75 N 52° W 16~4 24 5~674 62 ~'~ , 11,791 33° 30' 9809 85 163 91 N 47° W 1.796 03 5794 50 11,935 33° 00' / 9930 ~2 78 '42 . N 45° W .1851 48 5849 95 , 12,007 33° 00' 9991 00 39 21 N 450 W 1879 21 5877 : ~' CLOSUR5 6170 28' N 72~ 16~ W · ,,, SCALE 1"='500' 11,494' 10,901' IO,128' 8445* 51;55' ;~1§?' F~rm No. P--4 REV. 940~ STATE OF ALASKA suB~rr IN ~U~UCA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS OIL [~ OTHER W~-LL [] GA8 WELL 2. NAME OF OPEiR2kTOR Union 0il Company of California 3. ADDRESS OF OPERATOR 507 W. Northern Lights BlVd., Anchorage, Alaska 99503 4. LOCATiON OF V~TM Conductor 15, Leg 4, 1831'N & 1493'W from SE corner Section 29, TDN, R13W, SM. Am~EmC~bODE 50--133--20127 LEASE DESIGNA~ON AND S~IAL NO. ADL 17594 7. IF INDIA]~, ALOTTEE O]~ TRIBE NAME 8. U/N'IT,FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-13 (32-30) 10. FIELD AND POOL. OR WILDCAT McArthur River -Hemloek i1. SEC.. T., R., M.. (BO~'FOM HOL~ o~ Sec. 30, TDN, R13W, S.M. ' '12. P~R.MIT NO. 68-57 13. REPORT. TOTAL DEPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/XrD VOLLrNiES USED. PERFO.I{ATIONS, TESTS ~ RESULTS. FISH/NG JOBS. JI3'NK IN HOLE A_ND SIDE-TFLACKED HOLE AND A.NY O~I-IER SIGNIFICANT CI-LA/q-GES IN HOL~ CONDITIONS. TRADING, BAY, UNTT STATE ,G,-13 (32~.30,),, $EPTE~BE,R 1968 Opened 12-1/4" hole to 17" from 0-5125'. Ran 138 its 13-3/8" 61# J-55 Seal Lock csg. Hung w/Shoe @ 5125' & cmtd w/1690 sx Class'"G" mixed ~/101 Diacel plus 6% gel and 1% D-31 followed by 200 sx Class "G". Installed csg head & B~E. Drilled out float shoe & cleaned outto 5125'. Found junk on bottom (Broken portion of 17" hole opener shank). Drilled on junk @ 5125'. Ran Globe Junk basket, no recovery. Ran fine toothed bit on junk sub, drilled 5125~-5138' and recovered junk sub full of iron. Drilled* 12.-1/4" directional hOle to ~3~ unable to orient dynadrill to correct severe right hand turn. Ran in with open end drill pipe. Hung @ 9400', PluEged across dog let 9j0~.~rDl~l' w/300 sx Class "G" w/l% ¢1~-2. Tagged Plug @ 9171', Drilled"hard cement 'to ~2__0~". Dynadrilled, side- tracking origtnaj' hole.' Drilled 12-1/4" directional hole to 11407'. Conditioned hole for logs. Ran Schlumberger DIL & FDC logs. Conditioned hole for csg. Ran 281 jts D'5/8" cSg. 409, 43.5~, 47# N-80 & P-110'buttress csg. Hung w/shoe @ 11350'. Cemented thrOugh shoe w/!!00 sx ClaSs "G" mixed w/l% CFR-2. Drilled out floats and shoe and cleaned out cement to 11407'. Raised salinity of mud to 29000 PPmc1. Drilled 8-1/2" directional bole'to 11872'. Now drilling. RE .E!VED ,VIS,ON OF: ,MiN[-,S & MINERAL~ ANCHORAGE 14. I he.by ~~jhe ~r~. B. ~ ~ s,a~ /lC_ [.~ =~ Dis~. Drl~. Supt. ~,~ 10111168 , B.~." Ta~ley / " NOTE--RePort on this/otto is ~equked for each ca~e~dar momth, r eDardless of the status o~ oDeratioms, a~ must ~ file~ im ~p[~cate w~th the Division of Mi~es~Mi~erals by t~ 15th o~ the succeedin9 mo,th, unless othe~ise directed. Form No. P---4 REV. 9-3O-6; STATE OF ALASKA SUBMIT IN DEPLICATE O~L AND GAS CONSEI~VATION COMMIT'rEE A~ONTHLY REPORT O:F 'DRILLING AND WORKOVER OPERATIONS AP1 NI/SIERICAL CODE 50-133-20127 6. LFJkSE DESIG-N'ATION AXD SERIAL NO. ADL-17594 i,' .... ' ' 7. IF INDIAN, ALOTTEE OR TRIBE OIL ~ GAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. LrNIT,FA3UH OR LEASE NAAIE Union 0il Company of California Trading Bay Unit 3. ADDRESS OF OPERATOR 507 W, NQrthern LiKhts Blvd,, AnchoraKe, Alaska 99503 4. LOCA~ON O'F WEI.T. Conductor 15, Leg 4, 1831'N & 1493'W from SE corner Section 29, T9N, R13W, SM 9, WELL NO. State G-13 (32-30) 10. FIELD A-ND PO~)L, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M.. (BOTTOM HOLE OB.rECTrVE) Sec. 30, T9N, R13W, SM 12. PER/VIIT NO. 68-57 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA3~GES IN HOLE SI~E, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AINU) VOLLrNrES USED, PERFOt{ATIONS. TESTS A/NYD RESULTS. FISHING JOB~, JLrNK I/~ HOLE A24D SIDE-/-FtACKED HOLE A2N-D A~qY OTHEI{ SIGNIFICA/%IT C/-IAI~ES IN HOL3~ CONDITIONS. TRADING BAY UNIT STATE G-13 (32-30), AUGUST 1968 SPUDDED 3:30 AM 8/24/68 Drilled 15" hole to 621' ~ Opened hole to 22" to 621' Ran 15 Jts, 17-3/4" 0D', 17-1/8" ID, 0.312 wall, spiral weld casing. Hung with shoe @ 602'. Cemented w/750 sx class "G" w/2% CaC12. Drilled 12-1/4" directional hole to 3003' Twisted off DP @ 217' while drilling @ 3063'. Ran overshot and recovered all fish. Drilled 12-1/4" directional hole to 5125'. Opened 12-1/4" hole to 17" hole to 4690'. Broke leg off 17" hole opener @ 4690'. Opened 12-1/4" hole to 16" from 4690-4820'. Now opening hole. DtV~51OF,~ OF MINES ANCN©RA~E srGmm l.~ff /ll//A~ Dist. Drlg. Superintendent 9/9/68 ' .~- ' -' ~ TITL~ ___ DATE NOTE--Report on this f~rm is required for each calendar month, regardless of the status of operations, anO must ~ fJleU Jn dupJJcat~ with the Division of Mi~s ~ Minerals by the 15th of the succeeding month, unless othe~ise directed. FORM SA - I B 125.5M 8/67 MEMORANDUM TO: J-- FROM: State of Alaska DATE SUBJECT: FORM SA- I B 125.5M 8/67 iMEMORANDUM FROM: state of Alaska DATE : SUBJECTs Il - ARCO TD g768' o I I K-4 ., P.OP. B.U. _L,OC/ TMD 12,200' ~~_ TVD g~615 ~ 0-2 0-6 I ~4-2e) I i I I xxO 0-8 ~-~ 0 ~ (~-~) x (~ ' ~s) D-I (~4- 22) / ~-'~ / TON RI3W x / b (~4-~) / , / D-2 / / ~ (22-5) / / UNION OIL COMPANY OF CALIFORNIA J / ALAS~ DISTRICT / .-- WELL LOCATION MAP / ~ ~ UNION OIL CO. OPERATOR ~' UNION TRADING BAY STATE UNIT G-13 (3~-3o) DATE , ICALE Form P---.1 REV. 9~30-67 SUBMIT IN TRIPII .'E (Other instructions STATE OF ALASKA OIL AND GAS CONSERVATION ,CO,MMITTEE~ reverse side) APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 11~. TYP~ OF WORK DRILL [] DEEPEN J--I PLUG BACK J--I ~., NAME OF OP~TOR Union 0il Company of ,California 3. ADDRESS O~ OPEiR~TOR 2805 Denali Street, Anchorage, Alaska 99503 4.LOCATIO.N OF WELL Atsurface Conductor 15, Leg 4, 1851'N ~ 1495'W from SE cornez Sec 29; T9N, R1SW, S M. n. smc...~..a..~..mo~o~ · · ~o~z om~c~w> ,t pro~od~rod, zone Top Hemlock' 1980'S ~ lg.80,W of NE corner, Sec. 50, T9N, .R1SW, S.M. ~ -;~ ' ' .... 13. DIST~CE IN MILES AND D~ECTION F_IOM NEAREST TOWN OR.POST OFFICE* 12. 25 air miles ~.of:Kenai~Ataska : .. , , .. 14. ~ND INFO~A~ON: t~ Statewide su~t~ ~n~/or ~o. United Pacific Insurance Company B-55572 ~.~, $100 ~000.00 15. DIST*NCE FRO~ P~OPOSEb*~' ~";' ' ':- ": ~ ; ; C - "' ]16. ND. OF ~ IN'L~E -:'-; "~ "Jlt:.~O.-'aC~ ASSlGND " LOCATION TO NEAREST ~ J . J TO ~iS W~L PROP~TY OR LEASE L~E, ~. ' .' ~' '; : ' ' ; - J' ~~. ~-~ . ' ~'-' ' J * , ' ' (A~o to nearest drig unit if any) I 1 1 ~ 9~ J , ... · * . '. I . .~ ...... , . .- - .. 18. DISTANCE FRO~ PROPOS~ LOCA~ON ]19. PRO~S~ D~ ] 20. ROTARY OR CABLE TOOLS TO NEAREST WELL DRILL~G, COMPLETe, . -- . iL-., ._ .~ :. ' . , :- J ~.. o~.~I~ ~o~, ~. . ' '~ ' ~/ ' . ' I -~ ~ ": ~ .... 3850~' ....~- 1122'00'~ ~:~'10165:"VD' J' ' : Rotary 21. ELEVATION~ (Show whether DF, RT, GR, etc.) ' J~;. APPROX, DATE WORK WILL ST~T 99' Rt above MSL .~ ~ .. - ~ ~,. · .- - t July 1.. 23. ' ' '~ .... ' '' ~OP0~ ~ASING ~D: C~EN~NG PROG~ AP~ 50-133-20127 6. LFJ~E D~IGNA~ON A.ND SI~3~ NO, ^DL 17594 I. IF INDI.a~i~, ALLO'rrEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-13 (32-30) 10. FIELD AND POOL, O1~ WILDCAT McArthur River - Hemlock Sec. 30, T9N, R13W~ S.M. ....SIZE OF HOLE [,. SIZE OF C'~SING},I : wEiGI-fT~pE'"R F°~f: GRADrE i, sETTiNC DEPTH \'~ 1 ' ' ' QUANTITY'" 'OF , 22" .17-%/4" %]2 Wn~l Sniral Weld 600' ' '12'60 Sacks 17-1/8" 15-5/~',.':.~ .. 61~.~. ~. , J-SS- -~ ,5000'-~ -~ . -~.:' .2000 sacks 12-1/4" 9-5/8~', .... , 40. 43~.S.:. . 4,7.. .N. g--P 11500" ., : ;-2000,-. sacks 8-1/2" 7" ....: ,,- 2:0~-,:: ..... . . N-ga . ~11400,~12200 . 500 ' ' 'r" '- '; ' ', Cement 17-5/4" casingin-22J' hole, at 600'. In~:tall .20" Hydrill, Cement 15-3/8" casing in 17-1/8" hole ag, $.000!:i-~.. In:s~a!l BOPE. Drill:12-1/4'' directional kle to 11500'~. Run electric 1.ogs. Cement 9-$/8" casing. logs. Cement 7" liner 11400-12200'. Drill 8-1/2" directional hole to 12200'+. Run electric Complete for production. Bottom Hole Location' Approximately 2500'W & 1900'S of NE corner Section 50, T9N, R15W, S.M. rN ABOVE SPACE DItCH/BE FROPOSED PlqK)GRAbI: If proposal is t~ deepen or plug back, give data on present produciive zone and proposed new productive zone. If Proposal is to drill or deepen direct ionally, give pertinent data on st~bsurface locations and measu~d and true vertical depths. Give blowout preventer program. 34, Ik hereby certify that. the~.F~r-~e$o~-ii ~e ~d ~o~&c~ ...... ¢ ~: (This space for Sta~e office use) .!'-" q:! ," ; i :!' ,~;0~ .1~ ONS OF APPROVAL, IF AH: I YES DIRF, C,,~IONAL SURVEY E,EQUIP,.ED A.P.I. NUMERICAL CODle. ~.7ES o ~o ," m - t,3>',> ,.., PERMIT NO ~ ~['~'/ '~ `%' / APP, ROVAL DATE / /' , : /:, ~ /i ~ ~"~'~7 I:xecuHve Secretary · ' TITI_~, DATE ·See InstructiOns On Rever~e ~l~i~'~'°'i°' Committee =~District Land Manager
