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168-109
• • b ! to o IHilcorp Energy Well: G-16(PTD 1681090) Field: Grayling 03/11/2018 I Pressure (psia) I W$. 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 vim — - - 1000 lik- - Pressure-Temperature Profile — _� I- 1. RIH Overla ?/18/16 vs 3/11/18 C - 2. Static MIMI 2000 i --1111 In - IM MI la NM IIIIIIIIMMI UM 3000 pC 11111111111111111 11111111 IIMINEIMIIIIL UM 4000 V , _if5000 CD ik 6000 __,I , D t 7000 CD p 8000 - X _ 9000 -- — X — 10000 = = , _ 1W \ 11000 12000 ` i NM 13000 I I I 50 60 70 80 90 100 110 120 Temperature (Deg. F) 3-11-18 Pressure — Perfs 17-3/4" 13-3/8" 9-5/8" 7" TBG 3-11-18 Temp 2-18-16 Temp SCANNED EAR 2: 2.018 Report date: 3/19/2018 • • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Thursday, March 03, 2016 3:49 PM To: Wallace, Chris D (DOA) Cc: James Young; Wayne Johnson; John Waski;Zachary Rolph; Kenneth Wingard; Stan Golis Subject: G-16 (PTD # 168-109) Compliance Temperature Survey 2-18-16 Attachments: G-16 Temp Survey 2-18-16 vs 2-22-14.xls Hi Chris, Well G-16 (PTD 168-109)was granted a return to injection under Administrative Approval (AIO 5.005)on March 23, 2006. As required under the approval, a biennial temperature survey was run on 2-18-16. The survey(see attached) is consistent with the last survey run on 2-22-14. Although there are some small pressure anomalies uphole in this well, the repeated character of the anomalies show that downhole fluid containment has been maintained. The current survey confirms that all injected fluids are being contained within the approved zones of injection. Please contact me if you have any questions concerning the survey. Larry 777-8322 SCANNED MAR 1 5 2016 • 0 Hilcorp Alaska LLC Well:IG-16 Field:IGrayling 102/18/2016 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 _ — T 1000 Pressure-Temperature Profile 1 RIH Overlay 2014 2016 2000 3000 —__ 4000 - - 5000 -- CD 110W 6000 t- 7000 \\. -rQ CDD 8000 9000 100003 Ilk _ _ _ _ 11000ill .... .... 12000 NW 13000 I I I - i I 50 60 70 80 90 100 110 120 Temperature (Deg. F) 2-18-18 Pressure - Perfs 17-3/4" 13-3/8" 9-5/8" 7" — -TBG 2-18-16 Temp 2-22-14Temp Report date: 3/7/2016 • • PTD 16`1 106\ o IHilcorp Alaska LLC I WeII:IG-16 I FieId:IGrayling 102/18/2016 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0I I I 1000 Pressure-Temperature Profile I 1. RIH Overlay 2014 vs 2016 2000 I– -- I_ 3000 !- 4000 I 5000 I 11 I___ 6000 0 2 s 7000 0. CD0 8000 — 9000 10000 11000 — 12000 ■ IN NM 13000 1 1 1 - i 1 1 50 60 70 80 90 SCANNED rm 110 62017 120 Temperature (Deg. F) 2-18-18 Pressure – Perfs 17-3/4" 13-3/8" 9-5/8" 7" — –TBG 2-18-16 Temp 2-22-14Temp Report date:9/20/2016 • l66/07o Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Thursday, March 22, 2012 3:01 PM To: Regg, James B (DOA) Cc: Michael Dunn; Schwartz, Guy L (DOA) Subject: RE: G -16 (PTD # 168 -109) Compliance Temperature Survey Attachments: G -16 Schm 3- 25- 98.docx; G -16 temp survey comparison.jpg; G -16 TIO Report 3- 21- 12.xls Here are my thoughts, Jim. Be glad to come over and review this with you and Guy at your convenience. I had already asked the logging company the exact same question you are asking, why is the 2012 survey 'smoother' for 5000' than the 2010 survey (almost like the readings were averaged over a few feet at a time). They didn't have a quick answer and neither do I. The entire survey is cooler, so obviously the shut -in time was shorter, but why the return to noisy down deep ?? I believe the 'noise' is a result of very localized near wellbore rock (coals vs sands vs shales, etc) or cement differences, like the base of the 13 3/8" where 2350 sacks of cement were used when setting the casing (see attached schematic). But why did the 'noise' quit for those 5000'... don't know. Attached you'll also find a comparison slot of the more recent to • rve s with the iris inal baseline in June 2005. Since the baseline was run immediately after losing tbg x csg integrity, there can't be any uphole water entry due to a casing breach. Although smoother, the character of the ori• inal survey is easil discer • - ' • - - - - no • • ly indicatin that over the period of time survaysV there has not hpan any injected water exiting the casing even with all the small temperature spikes visible on the plot. The 2005 survey is also warmer than the others, indicating a longer shut -in time prior to running. This could also 'smooth' the data as more of the ambient rock temperature reaches the wellbore. The attached TIO plot also shows, as you state, that there is no indication of any communication out of the 7" casing over the timeframe of the last two surveys. .--> Temperature surveys are subjective, but we don't use temperature surveys by themselves. In conjunction with the TIO plots, their analysis confirm 1 - • - - • • - ,i1 re has occ . - • -, • , a er is exitin • the casin • ab• - e sacker. In the case of G -16, although I see many repeatable small temperature spikes (2 -5 degrees), I don't see a temperature response (10 -20 degrees) that indicates we are losing control of the injected fluids. Preferentially any uphole leak would be at a lower pressure and would be taking larger and larger portions of the injected water. I'm putting together a summary of the G -5RD CMIT efforts for another example of why we believe the risks of a stuck plug outweigh the benefits of a positive test (pressure test) when you have a valid negative test (comparison temp survey) at your disposal. Let me know if you would like to see more. I have a couple of examples where a temp survey shows downhole temperature responses that clearly indicate downhole conditions that have been explained and I'll have that G -5RD summary put together soon. Larry 5,04MEDMAR 2 9 `61'Z -16 S e: c From: Regg, James B (DOA) [mailto:jim.regg(aalaska.gov] Sent: Wednesday, March 21, 2012 10:25 AM To: Larry Greenstein Cc: Michael Dunn; Schwartz, Guy L (DOA) Subject: RE: G -16 (PTD # 168 -109) Compliance Temperature Survey Please provide Hilcorp's analysis of the G -16 temp survey; in particular the positive and negative temp shifts near base of 13 -3/8 ", at approximately 7500 ft, and just above perfs. 1 • • Also, the survey in 2010 is extremely noisy; what's the difference in 2012? Suggest providing analysis that compares to the baseline temperature survey run in this well. Tubing by Inner Annulus (TxIA) communication downholed is a given; that's the basis for AIO 5.005. TIO pressure plots (daily pressure monitoring data provided monthly) clearly indicate the pressure communication, and also appear to confirm there is no communication beyond the 7" casing. Temp surveys are so subjective; in this case I am not convinced the survey tells us anything more than the injection perfs are accepting water and not much can be deciphered about well barrier integrity. I would like to understand the reason for not performing a combination MIT (OMIT TxIA) to confirm the integrity of the 7" casing. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Larry Greenstein [ mailto :IgreensteinCa�hilcorp.com] Sent: Tuesday, March 20, 2012 1:39 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Michael Dunn Subject: G -16 (PTD # 168 -109) Compliance Temperature Survey Hi Jim & Guy, Well G -16 (PTD 168 -109) was granted a return to injection under Administrative Approval (AIO 5.005) on March 23, 2006. As required under the approval, a biennial temperature survey was run on 3- 17 -12. The survey (see attached) is consistent with the last survey run on 3 -3 -10. The current survey confirms that all injected fluids are being contained within the approved zones of injection. Please contact me if you have any questions concerning the survey. Larry 777 -8322 2 • • IHiicorp Energy I WeII:1G -16 I FieId:1Grayling 103 -17 -2012 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 V� E I I loon 1 1 '- Pressure- Temperature Profile 1. RIH Overlay 6 -25 -05 Baseline 2000 – — with 3 -3 -10 and 3 -17 -12 most 3000 , 1 1 4000 1 5000 w , 6000 d 7000 . C 8000 9000 _ wr 10000 ?_ ) 2_- 11000 _.. 1IL I 111 12000 is • 7.610 13000 I 1 I i I 1 I I I 50 60 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) Pressure 12 – Perfs 17 -3/4" 13 -3/8" 9-5/8" 7" — –TBG Temperature 12 10 Temp Temp 05 Report date: 3121/2012 S ot Pressure & Rate vs Time - Well G -16 3000 - 4500 2500 °V.2'' , ' a000 WON" w '` I 41 3500 I - - ___ . - --- 2000 - _ _ I t- 3000 3 V 250011 r2 1500 m et 2000 •9 5/8" 13 3/8" 1000 20" 1500 — Tubing • Vol 1000 500 -- --.. - - - - -- - -- -- - -- -- - -- - -- -. __ _ _... �� r L/ ►3 soo o, t ! O O O O O O O O O O O O _ _ . . . . . . . - - _ N N N N -. O O 8 8 — 8 n n 8 8 r 8 8 N 8 V M M N N O M O O O M M M N N N N N N N N N N N N N N N N N N N N A 2 n 2 2 2 n 2 2 O N O 2 O A 2 2 O W O ; N O 2 Date , 7" 9 13 3/8" 20" Tubing Vol TIO Report 03/20/12 1 2400 220 0 2650 4466 03/19/12 2400 210 0 2680 4536 Data Sheet 03/18/12 2400 210 0 2675 4651 03/17/12 2250 210 0 2650 767 03/16/12 500 21 200 0 600 3493 G -16 03/15/12 2400 210 0 2850 4280 03/14/12 2400 200 0 2850 4271 ' IIII 03/13/12 2400 r 200 0 2850 4255 INJECTION 03/12/12 2400 200 0 2850 4017 03/11/12 2375 ' 205 0 2800 3988 03/10/12 : 2375 : 205 0 2800 4161 Permit # 03/09/12 2375 ' 205 0 2800 4163 03/08/12 1 2375 '; 205 0 2800 4151 03/07/12 2375`!: 205 0 2800 4155 Admin Approval # AIO 5.005 03/06/12 2375 205 0 2800 4145 03/05/12 2360 200 0 2800 4148 03/04/12 2350;':" 200 0 2800 4149 API # 50- 733 - 20162 -00 03/03/12 2350 210 0 2800 4148 03/02/12 2350 200 0 2800 4158 03/01/12 2350 2. 200 0 2800 4154 01/31/2010 to 03/21/2012 02/29/12 2355 2':` 210 0 2800 4146 02/28/12 2350 21 ` 210 0 2800 4139 02/27/12 2360 2: 205 0 2800 4143 02/26/12 2360 2: 205 0 2800 4146 02/25/12 2360 2? 205 0 2800 4138 02/24/12 • 2360 2' 205 0 2800 4128 02/23/12 2360 2 205 0 2800 4104 02/22/12 2360 2_: 205 0 2800 4090 02/21/12 2360 2_ 205 0 2800 4099 02/20/12 2360 2* 205 0 2800 4125 02/19/12 2350 22 205 0 2800 4108 02/18/12 2350 2 205 0 2800 4118 02/17/12 2350 2:, 0 2800 4128 02/16/12 2350 24': 205 0 2800 4115 02/15/12 210 0 2800 3918 02/14/12 210 0 2800 3985 3/22/2012 3:42 PM - TIO Reports 7e.xls 1 1 Dolan G -16 TIO Report 3 -21 -12 G -16 • • Trading Bay Unit ALASKA DRILLING Well #G-16 UNOCAL 76 Actual Recompletion(3 /25/98) RKB to TBG Head = 41.35' CASING AND TUBING DET ∎ I I. SIZE NN GRADE CONN ID TOP It INI. ( NI 1 17 -3/4" .312 wall Weld Surf. 601' L .\ 13 -3/8" 61 K -55 Seal Lock 12.515 Surf: 5960' 2350 sx 9-5/8" 47 P -110 Butt 8.681 10,680' 12,416 1000 sx 9 -5/8" 47 N -80 Butt 8.681 8503' 10,680' 9 -5/8" 43.5 N -80 Butt 8.755 6296' 8503' 1 \_IDV Collar D 6172' 9 -5/8" 40 N -80 Butt 8.835 4009' 6296' 9 -5/8" 43.5 N -80 Butt 8.755 54' 4009' 9 -5/8" 47 N -80 Butt 8.681 Surf: 54' 7" 29 P -110 Butt 6.184 11,345' 13,663' 1300 sx 7" 29 N -80 Butt 6.184 Surf. 11,345' 7" DV Collar 6172' 6174' 1 Tubing: - " 4 „ 2 3 -1/2" 9.3 L-80 EUE. AB Mod 2.992" 0' 6508' 3 -1/2" 9.3 L-80 ST -L 2.992" 6508' 11,834' 3 Milr 5 G - JEWELRY DETAIL 1)11)111 ID Item 41.35" 3 -1/2" CIW DCB Tubing Hanger 3 -1/2" Butt x 3 -1/2" EUE G -2 I 11,842' 3.25 Baker K -22 Anchor Tubing Seal Assembly 2 1 L843' 3.25 Baker Model "84SAB40x32" Penn Pkr. 3.25" ID 11.848" 3.75 Baker Mill out Extension G - 4 11,891' 2.813" Baker "X ": nipple profile 11925" 2.992" Ball Seat Sub 12416L \ G -4 G -5 G -6 Bad Casing from 12,780 to 13,154'. Squeezed with 300sx cement on 4/3/78 12 780 FISH Baker Model DB Packer with seal bore extension 3/23/98 @13,384' Cmt Retainer 6/18/74 @13,462' HB -1 Junked Pkr 3/30/78 @13,482' Cmt Retainer 4/2/78 @13,482' PERFORATION DATA Accum Last HB -2 Zone Top Btm Amt SPF Perf Date Present Condition ' G -1 12,120' 12,145' 25' 12 4/25/87 Open f/ Injection G -2 12,164' 12,210' 46' 12 4/25/87 Open f/ Injection G -3 12,275' 12,315' 40' 12 4/25/87 Open f/ Injection G -4 12,335' 12,450' 115' 12 4/25/87 Open f/ Injection I G -5 12,520' 12,610' 90' 12 4/25/87 Open f/ Injection HB -3 G -6 12,685' 12,725' 40' 12 4/25/87 Open fl Injection 13,154 HB -1 12,845' 12,890' 45' 16 4/25/87 Open f/ Injection HB -2 12,904' 12,985' 81' 6/14/74 Cmt Sqz'd HB -2 13,005' 13,088' 83' 6/14/74 Cmt Sqz'd HB -4 HB -3 13,108' 13,142' 34' 6/14/74 Cmt Sqz'd HB -4 13,172' 13,270' 98' 20 4/25/87 Open f/ Injection ETD = 13,384' TD = 13,663" KB ELEV = 99' MAX ANGLE = 48.45 @ 11,067' G -16 Schm 3 -25 -98 REVISED: 11/5/97 - • Trading Bay Unit ' Well # G -16 U N O CAL 76 Actual Recompletion(3 /25/98) Wireline Problems: 2.25" LIB ran on 8/3/97 showed deep gouges on side and a smaller gouge in middle @ 12,220' Tubing Size: 3 -1/2 ", 9.3 #, N -80, Seal Lock Plastic Coated 2 -7/8 ", 6.4 #, N -80, Seal Lock Plastic Coated Minimum I.D. "X" Profile Nipple @ 12,816' 2.313" Max Deviation: 48.45° @ 11,067' Perforations: Open for Injection "G" Zone & Hemlock B -1 & B -4 Status: "G" sands 2102 BPD 3150 tbg press 2850 csg press Hemlock 4268 BPD 3150 tbg press 2850 csg press Correlation Log SWS FFD log dated 3/2/69 Water Injection Log 6/6/95 HB -4 216 BPD 3% HB -3 428 BPD 6% HB -2 559 BPD 7.8% HB -2 3,243 BPD 45.4% HB -1 434 BPD 6.1% G Zone 2,268 BPD 31.7% Discussion • A Water Flood Injection Profile ran on 7/6/95 shows the cmt squeezed intervals, HB -2 & 3, taking 86.6% of the water being injected into the Hemlock. • Tubing is in communication with casing. • Possible leak components are the "XA" sliding sleeve, Seal Assy., Packer or tubing. • Well head passed MIT. • Bad casing f/ 12,780' to 13,154'. Cmt sqz'd w/ 300 sx of class "G" on 4/3/78. G -16 Schm 3 -25 -98 REVISED: 11/5/97 16516143 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, March 21, 2012 10:25 AM To: 'Larry Greenstein' ' Cc: Michael Dunn; Schwartz, Guy L (DOA) Subject: RE: G -16 (PTD # 168 -109) Compliance Temperature Survey Please provide Hilcorp's analysis of the G -16 temp survey; in particular the positive and negative temp shifts near base of 13 -3/8 ", at approximately 7500 ft, and just above perfs. Also, the survey in 2010 is extremely noisy; what's the difference in 2012? Suggest providing analysis that compares to the baseline temperature survey run in this well. Tubing by Inner Annulus (TxIA) communication downholed is a given; that's the basis for A10 5.005. TIO pressure plots (daily pressure monitoring data provided monthly) clearly indicate the pressure communication, and also appear to confirm there is no communication beyond the 7" casing. Temp surveys are so subjective; in this case I am not convinced the survey tells us anything more than the injection perfs are accepting water and not much can be deciphered about well barrier integrity. I would like to understand the reason for not performing a combination MIT (CMIT TxIA) to confirm the integrity of the 7" casing. Jim Regg t I— AOGCC o� '' � t t1 AE" ' 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Larry Greenstein [mailto:Igreenstein@ hilcorp.com] Sent: Tuesday, March 20, 2012 1:39 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Michael Dunn Subject: G -16 (PTD # 168 -109) Compliance Temperature Survey Hi Jim & Guy, Well G -16 (PTD 168 -109) was granted a return to injection under Administrative Approval (AIO 5.005) on March 23, 2006. As required under the approval, a biennial temperature survey was run on 3- 17 -12. The survey (see attached) is consistent with the last survey run on 3 -3 -10. The current survey confirms that all injected fluids are being contained within the approved zones of injection. Please contact me if you have any questions concerning the survey. Larry 777 -8322 1 1 7 3 uG' « l b i :p Er,crc;y I Well:1G -16 I Field:IGrayling 103 -17 -2012 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 IL 110 Pressure - Temperature Profile 1000 _ 1. RIH Overlay 3 -17 -12 vs 3 -3 -10 4 2000 3000 4000 5000 II C) 6000 — 7 ci .141 2 lit_ ■ 7000 1111111 I d CI 8000 9000 10000 l 11000 12000 -- ii i l >! a wil 13000 I I I I I I I 50 60 70 80 90 100 110 120 130 Temperature (Deg. F) Pressure 12 – Perfs 17 - 3/4" 13 -3/8" 9 - 5/8" 7" — –TBG --- Temperature 12 10 Temp Report date: 3/20/2012 TR - l� • • F /6, & 0 I Hilcorp Energy I WeII:IG -16 I Field:IGrayling 103 -17 -2012 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 1000 - - Pressure- Temperature Profile 1. Going in hole 12300' RKB 2000 — 3000 4000 5000 a a) 6000 - G 2 7000 — CI) 8000 9000 10000 - 11000 — - 12000 13000 50 60 70 80 90 100 110 120 Temperature (Deg. F) Pressure — Perfs 17 -3/4" °-- 13 -3/8" 9 -5/8" 7" — — TBG Temperature Report date: 3/20/2012 • S Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 Centerpoint Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 ‘.vis\-Q550 Mobile 907 223 0128 Fax 907 263 7897 kcso -0 ®� Email jzager @chevron.com t� %kit -pao% November 16, 2011 � a-�(Z�� a, ® y NOV � 2 7 UIC Manager � L Its Thor Cutler, OCE -082 0 ®� e dtEC�l�® sJ U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave., Suite 900 , a f,tl i • Seattle, WA 98101 .t.... Re: Amended Request for Permit Transfer: Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC Dear UIC Manager: Please replace my letter dated November 15, 2011 requesting permit transfer of Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC. Union Oil Company of California ( "Union ") has entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp ") with an anticipated closing scheduled on or about December 15, 2011, assuming certain regulatory approvals are received by December 1, and all other Closing conditions are met. The actual closing date may vary depending on how quickly certain regulatory approvals are processed. The transfer of Union's interest to Hilcorp is conditioned on the completion of the transaction ( "Closing ") pursuant to the Asset Sale and Purchase Agreement by and between Union and Hilcorp. Union and Hilcorp will advise you upon Closing that the transfer has become effective, and Hilcorp has taken over Union's interest and operations, including the above referenced UIC Permit No. AK- 1I006 -A. Should the Closing for any reason not occur, Union will advise you that it has retained its interest. Environmental Protection Agency (EPA) Form 7520 -7, Application to Transfer Permit, is enclosed. Eight wells are permitted as candidate wells for Class I operation under this permit. These eight wells are: Dolly Varden Platform wells D -9RD and D- 15RD2, Grayling Platform wells G -5RD and G -16, King Salmon wells K -11 and K- 24RD2, and Steelhead Platform wells M -27 and M -30. Currently, only D -9RD has received written authori7atinn from EPA Region 10 to commence Class I injection. An agreement memorializing the transfer of UIC Permit No. AK- 1I006 -A from Union to Hilcorp is also enclosed. 1 of 2 UIC Manager • • US Environmental Protection Agency November 16, 2011 Page 2 We appreciate your attention to this request and apologize for the inconvenience. Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivar achevron.com or 263 -7685. Regards , ,_ i/l ' 4 ,_-- John 4er v r.....----- Enclosures: US EPA Form 7520 -7 Agreement to Transfer UIC Permit No. AK- 1I006 -A cc: John A. Barnes, Hilcorp Alaska, LLC Marc Bentley, ADEC Cathy Foerster, AOGCC 2 of 2 • • OMB No. 2040 -0042 Approval Expires 12/3112011 United States Environmental Protection Agency �tr EPA Washington, DC 20460 Application To Transfer Permit Name and Address of Existing Permittee Name and Address of Surface Owner Union Oil Company of California; P.O. Box 196247 State of Alaska, Department of Natural Resources Anchorage, AK 99519 -6247 550 West 7th Avenue, Ste. 800; Anchorage, AK 99501 State County Petmit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK- 11006 -A Section Plat . 640 Acns N Surface Location Description I I f I - t ' 1 I 1 , SC 114 of tie 114 of SW 114 of SW 114 of Section . _ Township 8n . Range 13w - -4- -I- -F - - -+ - -t ` Locate well in two directions from nearest lines of quarter section and drilling unit I I I I I I - r Surface 1- -I. , 4 Location 754 ft. frm (WS) S Line of quarter section I I I I I i and tl 38t. from (E/W) W Line of quarter section. Well Activity Well Status Type of Permit 4 - - 4 _ _ `� - �' - x Class I L , Individual I I I I I I --- Operating -7-1-7- ,__ Class II Modification/Conversion _L_ Ares 8 I N ! „ Brine Disposal X Proposed Number of Wells — — — —' - i Enhanced Recovery 1 I I I I I I Hydrocarbon Storage Class 111 Other Lease Number Sec Attached Well Number See Attached Name(s) and Address(es) of New Owner(s) Name and Address of New Operator Hilcorp Alaska, LLC; 3800 Centerpoint Drive Suite 100; Hilcorp Alaska, LLC; 3800 Centerpoint Drive, Suite 100; Anchorage, AK 99503 -5826 Anchorage, AK 99503 Attach to this application a written agreement between the existing and new permlttee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. • Certification I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, 1 believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed John "Lager, General Manager 11/15/2011 EPA Form 7520.7 (Rev. 12 -08) • Attachment to Form 7520 -7, Application to Transfer Permit One well is fully authorized for operation as a Class I well. An additional 7 wells are proposed candidate wells, but are not fully authorized for operation as Class I wells. The location map and surface well location shown on the front page of EPA Form 7520 -7 illustrates the location of the 1 authorized and operating Class I well. Well information for each of the 8 permitted wells is included on this page. Well API No. Lease Feet from Section Seward Meridian Line (Surface location) Sec Twp Range Authorized Well D -9R0 50- 733 - 20131 -01-00 ADL 018729 756 FSL/ 1138 FWL 6 8N 13W Permitted wells M -27 50- 733 - 20423 -00 -00 ADL 018730 974 FNL/ 531 FWL 33 9N 13W M -30 50- 733 - 20430 -00 -00 ADL 017594 967 FNL/ 520 FWL 33 9N 13W G -5RD 50- 733 - 20162 -01 -00 ADL 018730 1838 FNL/ 1487 FEL 29 9N 13W G -16 50- 733 - 20060 -00 -00 ADL 017594 1879 FSL/ 1381 FEL 29 9N 13W K -11 50- 733 - 20148 -00-00 ADL 017594 617 FSL/ 131 FEL 17 9N 13W K -24 RD2 50- 733 - 20330 -01 -00 ADL 018730 733 FSL/ 131 FEL 17 9N 13W 0-15 RD2 50- 733 - 20159 -02 -00 ADL 018729 754 FSL/ 1130 FWL 6 8N 13W FSL = Feet from south line of quarter section (feet south section line) FNL= Feet from north line of quarter section FWL= Feet from west line of quarter section FEL= Feet from east line of quarter section • • Agreement to Transfer UIC Permit No. AK- 1I006 -A This Agreement to Transfer UIC Permit No. AK- 1I006 -A ( "Agreement ") is made the 15 day of November, 2011 between Union Oil Company of California, a California corporation ( "Union "), and Hilcorp Alaska, LLC., a Delaware limited liability company ( "Hilcorp "), collectively referred to as the "Parties," or individually as a "Party." RECITALS WHEREAS, Union and Hilcorp have executed an Asset Sale and Purchase Agreement dated effective as of July 1, 2011, ( "ASPA ") whereby Union agreed to sell its therein described interests in the Cook Inlet Area to Hilcorp; and WHEREAS, Union's interests in the Cook Inlet Area include UIC Permit No. AK- 1I006 -A; and WHEREAS, Union wishes to effect the transfer of that permit to Hilcorp as authorized by regulation promulgated by the Environmental Protection Agency ( "EPA ") at 40 CFR § 144.38(b); and WHEREAS, the EPA requires a written agreement between Union and Hilcorp containing the specific date for transfer of permit responsibility, coverage and liability between them. Agreement to Transfer UIC Permit No. AK- 11006 -A • • AGREEMENT NOW, THEREFORE, in consideration of each Party's intent to consummate the closing of the ASPA, and for such other consideration the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows: 1. In the absence of notification to the Parties by the Director of EPA of the Director's intent to modify or revoke and reissue the permit, then effective as of the date of closing of the transaction contemplated by the aforementioned ASPA (the "Closing "), which Closing is projected to occur on or about December 15, 2011, subject to certain regulatory approvals being received by December 1, 2011 and all other Closing conditions being met, Union transfers and assigns to Hilcorp, and Hilcorp agrees to accept and assume, all of Union's rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A. The specific date for transfer of permit responsibility from Union to Hilcorp for this permit will be on the actual Closing date, which is anticipated on December 15, 2011, but may be later depending on when Closing actually occurs. ' 2. Should the Closing not occur for whatever reason, the Parties agree that Union shall retain all of its rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A, and Hilcorp shall have no rights, responsibilities, or liabilities under the permit. 3. In the event that the Director of EPA notifies the Parties of the Director's intent to modify or revoke and reissue the permit, then, assuming the Closing will nevertheless occur, Union shall undertake commercially reasonable efforts to cooperate with Hilcorp should it 2 Agreement to Transfer UIC Permit No. AK- 11006 -A . • choose to engage with EPA while the Director works to modify or revoke and reissue the permit. 4. Notices shall be made as follows: Union: Steve Wright Asset Development Manager 3800 Centerpoint, Dr., Suite 100 Anchorage, AK 99503 (907) 263 -7865 sswr ©chevron.com Hilcorp: John Barnes Senior Vice President Exploration and Production - Alaska 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 (907) 263 -7739 5. This Agreement may only be amended by written agreement signed by a duly authorized representative of each Party. 6. Except as set forth herein, this Agreement shall be binding only upon, and inure only to the benefit of, the Parties and their respective successors and assigns. No Party shall assign its rights or benefits under this Agreement without the prior written consent of the other Party. 7. This Agreement shall be governed by the laws of the state of Texas. 3 Agreement to Transfer UIC Permit No. AK- 11006 -A • . 8. The Parties have jointly drafted this Agreement, and this Agreement shall not be interpreted against or in favor of either of the Parties on the ground that any Party participated in drafting this Agreement. 9. This Agreement constitutes the entire agreement and understanding of the Parties with respect to the matters addressed herein. 10. In the event that there is any conflict between terms and conditions of this Agreement and the ASPA, the terms and conditions of the ASPA shall prevail. 11. No Party or representative, agent, or attorney for a Party has made any representation or warranty to influence the execution of this Agreement that is not expressly contained in this Agreement. 12. This Agreement may be executed in counterparts, all of which • together shall constitute one and the same instrument. 13. By execution of this Agreement, each of the Parties hereto represents and warrants that they have the corporate power and authority to execute and deliver this Agreement and that each of the Parties has the power and authority to make and carry out its obligations hereunder. WHEREFORE, this Agreement shall become fully enforceable and effective in all respects on the latter of the two dates appearing below. 4 Agreement to Transfer UIC Permit No. AK- II006 -A • Union Oil Company of California, Hilcorp Alaska, LLC, a a California corporation Delaware limited liability company �` By: / .:.a. By: o-- ------ Name: J - ^r Name: — la � ^,►� 4tFA Its: ___Akffr' - rct Its: V 1 Date: .Na ti. /4/ 1( Date: ifVflV IS 1 2 -o 11 5 Agreement to Transfer UIC Permit No. AK- 11006 -A • Maunder, Thomas E (DOA) Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Tuesday, March 09, 2010 9:23 AM ~\S~ ~~ To: Brooks, Phoebe L (DOA) Cc: Lambert, Steve A; Greenstein, Larry P Subject: TBU G-16 (168-109) Compliance Temperature Survey Attachments: G-16 Temp Survey.zip Pr ~~ S `~Q~ Steve, When you send in temperature surveys complying with a AA requirement, please be sure you copy them to Phoebe so she can make sure entries are made into the well records. Larry, Would you please be sure all the engineers are aware of the need to send such documentation to Phoebe? Regarding the specifics for the newest temperature survey for TBU G-16 (168-109); I concur with your assessment that this latest temperature survey confirms that the injected fluid is exiting the wellbore at the perforations. This latest survey agrees well with the survey conducted 3/6/08. Also, when sending well information, please include the well name and permit to drill number in the subject line. Call or message with any questions. Tom Maunder, PE ~ " AOGCC From: Lambert, Steve A [mailto:salambert@chevron.com] Sent: Tuesday, March 09, 2010 8:36 AM To: Maunder, Thomas E (DOA) ~'f~,> ~~~~"~~' ~~~ ~p .- ~l~~' Cc: Greenstein, Larry P; Cole, David A Subject: G-16 Compliance Temperature Survey Well G-16 (PTD 168-109) was granted Administrative Approval (AIO 5.005) for continued water injection on September 7, 2005. As required under the approval, afollow-up survey was run on March 3, 2010. The survey confirms that all injected fluid is exiting the wellbore at the perforations. If you have any questions regarding the attached survey please contact me. 3/9/2010 • Chevron Well: G-16 Field: Grayling 03-03-2010 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 Pressure-Temperature Profile 1000 -- _ _ 1. Going in hole TVD 2000 3000 r. 4000 - ~ I .~ D ~ 5000 iH I L Q I ~ 6000 7000 - I - I 8000 - 9000 - 10000 60 70 80 90 100 110 120 Temperature (Deg. F) 3-3-10 Pressure --- 13-3/8" - -TBG Perfs 9-5/8" 3-3-10 Tem 17-3/4" 7" 3-6-08 eport sate: G-16 Compliance Temperatrure ~ey Page 1 of 1 • Regg, James B (DOA) From: ~,. Lambert, Steve A [salambert@chevron.com} '~ ~~~'~~ ~~ ~~T Sent: Tuesday, March 18, 2008 10:35 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P Subject: G-16 Compliance Temperatrure Survey Attachments: G-16 Temp comparison 3-18-08.zip Well G-16 (PTD 168-109) was granted Administrative Approval (AIO 5.005) for continued water injection on September 7,2005. As required under the approval, afollow-up survey was run on March 6, 2008. The survey confirms that all injected fluid is exiting the wellbore at the perforatitons. If you have any questions concerning the attached survey please let me know. «G-16 Temp comparison 3-18-08.zip» ~~~ pRR ~ ~ 2008 3/28/2008 i ~ Chevron Well: G-16 Field: Grayling Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 1000 2000 3000 4000 5000 .-. a+ d 6000 ~ 7000 Q D 8000 9000 10000 11000 12000 13000 60 70 80 90 100 110 120 Temperature (Deg. F) 3-6-08 Pressure - Perfs - 17-3/4" 13-3/8" 9-5/8" 7" - -TBG 3-6-08 Temp 2-6-08 Temp 130 Report date: 3/2812008 • hevron Well: G-16 Field: Grayling Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 1 2 a .... e r d D H L ~+ a a~ o i 60 70 80 90 100 110 120 Temperature (Deg. F) 3-6-08 Pressure - Perfs -- 17-3/4" 13-3/8" 9-5/8" 7" - -TBG --3-6-08 Temp --2-6-06 Temp 130 Report date: 3/28/2008 • • Page 1 of 2 Regg, James B (DOA). From: Regg, James B (DOA) Sent: Wednesday, November 14, 2007 3:38 PM ~~`~~'0~ To: 'Greenstein, Larry P' ~~~~ Subject: RE: Missing MITs Thank you for the quick response. Not sure how I missed it, but GP 53 is on the quarterly LTSI report. We do not need anything further for that well at this time. Regarding TBU G-16, I found the request from Unocal, and approval dated 3/23/2006 in our files; info did nat get entered into the database systems. I've gone back and reviewed the pressure and rate histories for the well (info you provide every month per AIO 5.005) - I do not see any unusual behavior for the G-16 we11. Because of all the diagnostic work done in support of the approval to place G-16 back on injection, it would be confusing to try to tie the anniversary date to the mast recent mechanical integrity demonstration as we normally do with admin approvals. So, as we discussed this afternoon, the anniversary date for the temperature survey in G-16 will be March_23, 2006; next temp survey should be done in March 2008. Jim Regg ,. ~a AOGCC ~U 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 _. .,M From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Monday, November 12, 2007 9:01 AM To: Regg, James B (DOA) Subject: RE: Missing MITs Jim, The GP53 well is on the LTSI list of wells because it has been shut-in since 12104 right after we completed the temp survey for the original AA. You should be getting the LTSI report on this well every quarter (last one sent was an 1014). For G-16, we have not done the compliance temp survey yet. Althought AA 5.005 was apraved on 917!05 which would routinely lead to a 9107 campliance temp survey date, there is more to this story. You should have this in your records too. We noticed a casing leak on 9128/05, after the AA approval. A number of diagnostic temp and injection logs were performed and were approved as adequate proof of integrity by 12122105. We requested to return this well to injection with these logs as backup on 3113306. Permission for injection was granted on 3123106. We had planned on using this 3106 date as our two year anniversary date for the oompliance temp survey and not the original 9105 date of the AA due to ail the other follow-up ioggingldiagnostics done to this well. I apologize, Jim, for not presenting this to you earlier, f felt we wauld be meeting the intent of the two year compliance cycle using the 3/06 date of the return to injectian as opposed to the original AA date of 9105. After you review the follaw-up diagnostics for G-16, if you still want us to hanor the original 915 AA date far anniversary purposes, f°]! get the compliance temp survey arranged and the results to you as quickly as possible with my apologies. Thank Jim. Larry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 09, 2007 5:05 PM • M Page 2 of 2 To: Greenstein, Larry P Subject: Missing MITs Please provide the following (compliance with admin approval requirements): 1) GP 53 (PTD 196-014); AIO 11.003 -well should be added to either the Granite Pt monthly injector report of the LTSI report (SI since12/2004). Admin approval requires monthly report of pressures. 2) TBU G-16 (PTD 168-109); AIO 5.005 -temp survey was due 9/7/2007; was a survey completed? Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 e e FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Steve Lambert Advising Reservoir Engineer U nocal Alaska P..O. Box 196247 Anchorage, AK 99519-6247 c (~ . RE: TBU G-16 (PTD 168-109) Request to Resume Injection Dear Mr. Lambert: The Alaska Oil and Gas Conservation Commission ("AOGCC") hereby grants Unocal Alaska ("Unocal")'s March 13, 2006 request to resume injection in Trading Bay Unit ("TBU") G-16. The conditions of Administrative Approval AI05.005 remain in effect. Administrative Approval AI05.005 issued September 7, 2005 authorized Unocal to continue water injection into TBU G-16 with tubing x inner annulus ("T x IA") communication. Ru!~ 4 of AI05.005 required the well to be shut-in if any change was noted in the operation of the well and Rule 5 required express Commission authorization to return the well to service. When returned to operation in late September 2005, the pressure communication that had prompted the administrative request was absent. The well was shut-in on October 5 and the Commission notified on October 6. Unocal obtained sundry approval (305-390) to conduct diagnostic testing to determine the causes for the pressure behavior. Unocal performed a series of diagnostic temperature surveys after pumping seawater into the IA and tubing. Based on the diagnostic information, it is Unocal's assessment that all fluid is being injected into the perforated intervals and that there is a packer leak that allows the pressure communication. After reviewing the submitted information, Commission Staff concurs with Unocal's assessment. Accordingly the conclusions of AI05.005 are affirmed and the Commission continues to believe that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for Mr. Steve Lambert March 23, 2006 Page 2 of2 e e reconsideration is considered timely if 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. A person may not appeal a Commission decision to Superior Court unless reconsideratio s been requested. orage, Alaska and dated March ,.~ 2006. ~ Daniel T. Seamount, Jr. Commissioner qjbfJ;k~ Cathy . Foerster Commissioner ·'..i' e e Chevron === Steve Lambert Advising Reservoir Engineer Unocal Alaska Union Oil Company of California Box 196247 Anchorage, Alaska 99519-6247 Tel 907-263-7658 Fax 907-26~~? salambert@èifWi .....'" _.P March 13, 2006 M/ii( llla3/(<e .' "1 1 1l 20 Oil & " Os 083 c,,, A i!JfJ$ " fJC!¡Of. . 1.J(}111f!¡,' 'De 'lIS/Oil Thomas Maunder Alaska Oil and Gas Commission 333 W. 7th Ave., Suite #100 Anchorage. Alaska 99501-3509 Dear Tom: \(0'6-\0 ~ Unocal requests permission to reinstitute injection into well G-16 under the Administrative Approval granted this well on September 7, 2005. This request is based on the successful testing of this well over the period of January 19 to February 6, 2006. The results of the test are presented in the attached Summary. To support this request, Unocal submits the following information and documentation: 1. Summary of Well Status and Test Results 2 Sundry notice of operations (Form 404). 3. Temperature Surveys run before and after injection. Well G-16 has exhibited tubing and casing communication since being worked over in 1998. Pressure was maintained on the casing to prevent cross flow. 1:-: !Elte May 2005, the casing showed an increase in pressure after being bled off and on June 6 the weli N35 shut in. Injection into G-16 was resumed on September 27,2005 following receipt of the Administrative Approval. Upon being returned to injection, the casing pressure remained at zero. This was a concern since the tubing was known to be in communication with the casing. The well was shut-in on October 5 due to apprehension about a possible casing leak. The well remained shut-in until the test was initiated on January 19, 2006. The testing proved the integrity of the well casing. It is likely that the fluid is communicating past the packer causing the pressure on the casing. If approval is received to resume injection, pressure will be maintained on the casing. If casing pressures change dramatically, the injection will be shut-in and temperature surveys will be run again. It is proposed that temperature surveys be run on this well every 6 months for the first year of injection to confirm that injection is being contained within the zone of interest. If no problems are detected, the well will be tested on a 2 year cycle to confirm integrity. ~0\~ Steve Lambert cc: M IT book Well File Chevron === e e © Chevron 2005 DOC ID Legal Entity e e Well History Chevron - · G-16 was drilled and completed as a Hemlock bench 1-4 producer in May 1969. · The well was converted to injection in June 1974. Benches 2 and 3 were squeezed and bench 4 was frac. stimulated. · In April 1987 the G-1 thru G-6 sands were added to the completion. · The well was worked over in March 1998 to replace corroded tubing. · By April 1998 there was 1100 psi on the tbg. - csg. annulus. The well passed a standard MIT on April 19. © Chevron 2005 DOC ID 2 e e Well History continued... Chevron III · It is believed that the seals in the packer were leaking. In June 1998, agreement was received from the AOGCC to continue injection with 2000 psi. maintained on the annulus. · A standard MIT was completed and passed on February 19, 2005. · Following a reduction in casing pressure, an increase in casing pressure was observed and on June 6, 2005 the well was shut-in. · Administrative Approval to resume injection was received on September 7,2005. · Injection was initiated on September 27. No pressure was seen on the annulus and the well was shut-in on October 5, 2005. © Chevron 2005 DOC 10 3 Well bore Schematic RKB to TBG Head = 41.35' DVCollar @O172' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. e 17-3/4" .312 wall Weld Surf. 601 ' 13-3/8" 61 K-55 Sea! Lock 12.515 SurE 5960' 9-5/8" 47 P-II0 Bl'tt 8.681 10,680' 12,416 9-5/8" 47 N-80 Butt 8.681 8503' 10,680' G-1 9-5/8" 43.5 N-80 Butt 8.755 6296' 8503' G-2 9-5/8" 40 N-80 Butt 8.835 4009' 6296' 9-5/8" 43.5 N-80 Butt 8.755 54' 4009' G-3 9-5/8" 47 N-80 Butt 8.681 Surf. 54' 7" 29 P-IIO Butt 6.184 11,345' 13,663' 12.410' G-4 7" 29 N-80 Butt 6.184 Surf. 11,345' 7" DV Collar 6172' 6174' Tubing: 3-1/2" 9.3 L-80 EVE. AB Mod 2.992" 0' 6508' 3-1/7" 9.3 L-!IQ ST-L 2.992" 6508' 11,834' 12.780' Chevron III CMT 2350 sx 1000 sx 1300 sx e HB-1 HB-2 HB-3 13,154' HB-4 ETD = 13,384' TD = 13,663" KB ELEV = 99' MAX ANGLE = 48.48@11,067' © Chevron 2005 DOC ID 4 e e Chevron III Current Conditions · G-16 is shut-in. · The well is known to have communication between the tubing and the tbg.- csg. annulus. · When the wel.1 was placed on injection on September 2'7, 2005, no pressure was seen on the annulus. Due to concerns about csg. integrity the well was shut-in. · On January 20,2006 injection was initiated down the annu'us for 24 hours. Temperature logs were run to tr'ý to identify the location of the communication. · Injection was then initiated down the tubing for an extended test and additional temperature logs were run. © Chevron 2005 DOC ID 5 Pressure Readings During Annular Injection 1/19-20/2006 Chevron III , Tbg. 7" Csg. 9 5/8" 13 3/8" 20" Csg Rate Press. Press. Csg. Csg. Press. (BWPD) ( PSI) (PSI) Press. Press. (PSI) Date (PSI) ( PSI) e 1-19-2006 0 0 110 215 220 0 1-20-2006 374 465 1595 200 235 0 e Pressures and rates at the start and the end of injection test. © Chevron 2005 DOC ID 7 Temperature Survey Following Annulus Injection Chevron III 1000 --or ':j"cH;" I I -I o o 500 1000 Pressure (psia) 1500 2000 2500 3000 Survey 12 hours after injection shut-in 2000 i I . , Baseline prior to injection e 3000 Survey following 24 hours of injection i ~ 8000 -- . 9000 e 70 80 90 100 110 120 130 140 150 Temperaturt~ (Deg. F) ~-1-1-o6 Pressure - Perfs -17-3/4" --9-5/8" -7" - - lBG -1-20-06 Temp -1-21-06 Temp -13-3/8" -1-1-06 Temp © Chevron 2005 DOC ID 8 Chevron III Detail of Shallow Temperature Survey e Survey following 24 h of injection Survey 12 hours after .injection shut-in e © Chevron 2005 DOC ID Pressure (psia) 0 500 1000 1500 2000 250C 3000 3500 4000 4500 5000 0 I----- y J 100 \ rt..V -"r-- I---- 'I I 200 ì-- 1--- 1- ~:--- -- """ 300 ~- .-~'\ Ì"\ , ~ - 400 t...--- -- ~ ~ I - - I ~ ..........ì I - our!!- I', ./ I - 600 ~1 ..- ./ / ~ I 700 ~ V l/ A ~ I I .-. 800 ,/"'/ A t7 1» I .! 900 ¥ ,/ / /' : / /11" VI I .s::. 'S. 1100 / I II I ~ 1200 I f I 1300 ) I 1400 I 150-d I ,600 1700 I 1800 1900 I I 2000 60 70 80 90 100 110 Temperature (Deg. F) -1-1-06 Pressure - Perfs -17-314" -13-3/8" l -9-5/8" -7" - - TBG -1-1-06 Temp I -1-20-06 Temp -1-21-06 Temp I Baseline prior to injection 9 e e Conclusions from Annulus Injection · The 59 degree injection water is being warmed by adjacent wellbores near the surface. · No obvious exit points exist in the annulus. Chevron III · After injection, the well shows cooling all the way to the perforations, indicating all of the water is being injected into the formation. · No pressure was seen on the exterior casing strings while injecting into the 7ft casing. This supports the fact that there is no casing leak. © Chevron 2005 DOC 10 10 Pressure Readings During Extended Injection Test Down Tubing 1/21-2/6/2006 Chevron === e Tbg. 7" Csg. 9 5/8" 13 3/8" 20" Csg Rate Press. Press. Csg. Csg. Press. (BWPD) (PSI) (PSI) Press. Press. (PSI) Date (PSI) (PSI) 1-21-2006 667 1600 1250 205 260 0 1-25-2006 835 1850 1100 200 260 0 2-05-2006 1331 2400 1150 210 300 0 e © Chevron 2005 DOC 10 11 Chevron Temperature Survey Following Tubing === Injection P'essure (psia) 500 1000 1500 2000 2500 3000 3500 4000 4500 ~ 1000 n. , e I i 2000 . --. i 3000 . . 4000 I 6000 Ii Baseline survey é 1" 7000 .. I == ,I 1; "ð. Q) 8000 C 9000 e 10000 Survey following 11000 extended injection 12000 I 2-06-2006 13000 14000 60 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) -1-1-06 Pressure - Perfs -17-3/4" -13-3/8" -9-5/8" -7" - - l13G -1-1-06 Temp -2~-06 Temp © Chevron 2005 DOC ID 12 Conclusions from Tubing Injection Chevron === · The 59 degree injection water is being warmed by adjacent well bores near the surface. e · There are no obvious leaks in the wellbore. e · After injection, the well sho'ws cooling all the way to the perforations, indicating all of the water is being injected into the formation. · No pressure was seen on the exterior casing strings while injecting into the tubin~l. This supports the fact that there is no casing leak. © Chevron 2005 DOC ID 13 e e <c:;;.r' L_,~,.~~ I! \~? G=..'ë:J STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS HJl R ,.fA, 1 I.{ 2006 Gm,/:}, C¡i1\r;:¡¡rl)¡:li.0/·r . ;.)ilL", If A";"--Ò, oJi Ihl¡;ÛìGïage ~ " 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other ~ Injection Test Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development D Exploratory D 68-109 3. Address: Box 196247 Anchorage, Alaska 99519 Stratigraphic D Service 0 6. API Number: 50-733-20162-00 7. K8 Elevation (ft): 9. Well Name and Number: 99' G-16 ~. P~~perty Designation: 10. Field/Pool(s): ADL 17594 McArthur River Field Tyonek G and Hemlock 11. Present Well Condition SU",íT:~'~': Total Depth measured 13,663' feet Plugs (measured) true vertical 10,229' feet Junk (measured) Effective Depth measured 13,482' feet true vertical 10,012' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 601' 173/4" 601' 601' 2,630 1,020 Surface 5,960' 133/8" K-55 61# 5,960' 4,568' 3,090 1,540 Intermediate 12,416' 9 5/8" N-80 40# 12,416' 9,249' 5,750 3,090 Production 13,663' 7" N-80 29# 13,663' 10,129' 8,160 7,020 Liner Perforation depth: Measured depth: 12120-12145,12164-12210,12275-12315, 12335-12450, 12520-12610, 1¿5~5-12725, 12845-12890, 13172-13270 True Vertical depth: 9057-9076,9090-9124,9173-9202,9217-9300, 9350-9414, 9465-9491, 9571-9601, 9783-9846 Tubing: (size, grade, and measured depth) 31/2" 9.2# N-80 12,805' Packers and SSSV (type and measured depth) Permanent Packer 11,843' 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: Shut-in Subsequent to operation: Shut-in 14. Attachments: Summary of Results, Proposal to Inject 15. Well Class after proposed work: Copies of Logs and Surveys Run Temperature Logs Exploratory D Development D Service 0 Daily Report of Well Operations 16. Well Status after proposed work: r1'^ oilD Gas D WAG D GINJ D WINJ 0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or NIA if C.O. Exempt: 305-390 ...\ Contact Steve Lambert ;r P';n,,"Name ~tB"elh:~ Title Advising Reservoir Engineer t Signature h~:J 1z . Phone 263-7658 Date 3/13/2006 - , --- -- _.~-- . - ""II" ¡;'UUIIIIl ~"~..'c,, VIIIY Junocal e I well: G-16 e Field: GraYling o o 100 200 300 400 500 600 700 800 900 1000 1100 _ 1200 - $ 1300 "'" -: 1400 ~ 1500 I J: 1600 - 2' 1700 C 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 60 500 1000 1500 Pressure (psia) 2000 2500 3000 3500 4000 4500 5000 I 4 1\ .. ¡ i \ ill' -- - I ~ \ '-L.. ~ i --....... ~ f --- -J \ I " -- '" , ~ -J , -,\ , } ~ ! , ~ "', '\ 1 -¡ ./ j , I } ./ ---- .-- 1 1 J ¡ I ~ 1 I i \ ...."",. ~ \ . ~..,' . I -'" :/ Baseìiri~ Temperature I \ ~ /' I j f /v /'/ I 1 1 / / I I , , í J Temperature Following ~ 1 j I J Injection Down 1 ( ----J J I Annulus ¡ 1 i ........ J \ ~ Temperature 12 Hours I , ----... After Injection Down . I Annulus I I i- -- I J i \ ~, , , 1 ~ '¡ \ ~ \ 1 i j \ 1 -, , 1 ¡ , ..J ~ j t \ I I ¡ I . ¡ 70 80 90 100 110 Temperature (Deg. F) 1-1-06 Pressure 9-5/8" 1-20-06 Temp Perfs 17 -3/4" -TBG 13-3/8" 1-1-06 Temp 7" 1-21-06 Temp Report date: 3/712006 · STATE OF ALASKA e AlA~ Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS rVEO 1 4 2006 /" . r,¡ommlssiu[, Anchorage 1. Operations Abandon Repair Well Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: 7. KB Elevation (ft): 8. Property Designation: Plug Perforations Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate Other.¡ Injection Test WaiverO Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 68-1 09 ~ Service 0 6. API Number: 50-733-20162-00 Box 196247 Anchorage, Alaska 99519 9. Well Name and Number: 99' G-16 . ADL 17594 11. Present Well Condition Summary: 10. Field/Pool(s): McArthur River Field Tyonek G and Hemlock Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 13,663' feet true vertical 10,229' feet measured 13,482' feet true vertical 10,012' feet Length Size MD 601' 173/4" 601' 5,960' 133/8" K-55 61# 5,960' 12,416' 9 5/8" N-80 40# 12,416' 13,663' 7" N-80 29# 13,663' Plugs (measured) Junk (measured) TVD Burst Collapse 601' 2,630 1,020 4,568' 3,090 1,540 9,249' 5,750 3,090 10,129' 8,160 7,020 Measured depth: 12120-12145,12164-12210,12275-12315, 12335-12450, 12520-12610, 12685-12725, 12845-12890, 13172-13270 True Vertical depth: 9057-9076, 9090-9124, 9173-9202, 9217-9300, 9350-9414, 9465-9491, 9571-9601, 9783-9846 Tubing: (size, grade, and measured depth) 31/2" 9.2# N-80 12,805' Packers and SSSV (type and measured depth) Permanent Packer 11,843' 12. Stimulation or cement squeeze summary: Intervals treated (measured): "{ 'if Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Shut-in Shut-in 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: Summary of Results, Proposal to Inject Copies of Logs and Surveys Run Temperature Logs Daily Report of Well Operations Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or NIA if C.O. Exempt: 305-390 Contact Steve Lambert Printed Name Signature Title Advising Reservoir Engineer Date 3/13/2006 ..J:b .; ··IS-: }£ ~ 5000 - ....... CD 6000 ~ - - C 7000 :E I J:: ....... c.. 8000 CD C 9000 10000 11000 12000 13000 14000 60 ~^- ^^" "~,~.....~ -~-~--I o o 1000 Pressure (psia) 2000 2500 3500 4000 4500 3000 500 1500 1000 2000 3000 4000 70 100 130 150 140 110 120 80 90 Temperature (Deg. F) 1-1-06 Pressure 9-5/8" 1-20-06 Perfs 13-3/8" 1-1-06 Temp 7" 17 -3/4" -TBG 1-21-06 , , _ 1200 ... m 1300 ~ -: 1400 ~ 1500 I ~ 1600 ... g. 1700 C 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 60 I I l · o o 100 200 300 400 500 600 700 800 900 1000 1100 Pressure (psia) 2000 2500 3000 5000 500 1000 1500 3500 4000 4500 \ I I I I \ I I \ I --......... \ I \ \ ! I I ~ I I I \ '" \ ./' I ........ ^-~-- \ I } /' ------ .-- -~ I I I \ I ! ~ 1 I I I I \1 I I I , I ~I I I I / ,.r I I / ! ~._.~ I I , f I Iflitlrølì'J I I I I I ( J. ---~.._-- . ì I ~( I I I ----- I ~i1i_' ~~-- " I I 1 ~ I I I I 1 I I I I I , I I I ] I I I I i I I I I I I I I I I I I I I I !¡ \ I . m 70 80 90 100 110 1-1-06 Pressure 9-5/8" 1-20-06 Temp Temperature (Deg. F) I I Perfs ------Ü -3/4';--~~-~ --13-3/8"~1 7" - -TBG 1-1-06 Temp I 1-2_'1..:-..Q~~~m~.. _ ~ I Report date: 3/7/2006 5000 - ....... CD 6000 CD ..... - ... C 7000 :E I J:: ....... c.. 8000 CD C 9000 10000 11000 12000 13000 ------------- _____________________n_n______ _ ___________m_n____ o o 500 Pressure (psia) 2000 2500 4000 4500 1000 1500 3000 3500 1000 2000 3000 4000 14000 60 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) 17-3/4" 13-3/8" 9-5/8" 7" -TBG 1-1-06 2 -6-06 (C~) ~.r,' : . r~\\ ~? i~ \<',\ i: l! 1J \, !! i ,E' tì1JJ! i; í i-~ ~ ¡ r r i 1\..':- ' LJ.! J '~..h w l.=1J ) ;(ñ""\~ i'i-[;:¡ ~,.r'\' ~\ :'l: JII! :.' L., , ¡"P'I" \ I I I I :_r] I :1.J \ ¡ ! il )1 i :jirll\, \(,::!.J i~j ~':..J \~ ) /0:\ (.",.;11\. \ : /lId / iï=l \ :_" u I / / I .I .I j' FRANK H. MURKOWSKI, GOVERNOR AlASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Lambert Advising Reservoir Engineer Union Oil Company of California P.o. Box 196247 Anchorage, Alaska 99519 'Io~/Ioq Re: McArthur River G-16 Sundry Number: 305-390 SCANNED, DE C ,. t 2005 Dear Mr. Lambert: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~~ay of December, 2005 Encl. ur.'n:u-~uuo jUt U(J' j(J HIl _ ) _. _ . rAX NU, ~ (~:F STATE OF ALASKA ~)-t . ,=~ ALASKA OIL AND GAS CONSERVATION COMMISSION :íU APPLICATION FOR SUNDRY APPROVALS 20 AAC 25,280 Operational shutdowl"I U Plug Parlorations 0 Perforate New Pool n 4. Current Well Class; 1. Type õf Request: Abandon U Alter casing 0 Change âp'proved program 0 '2, Operator Name:· . Union Oil Compnay of California -2. Address: P.O. Box Hla247 Anchorage Alaska. 99519 7. KB Elevation (tt)~ 99' 8. 'Property Oesign'ation; ADL 17594 ~11. Total Depth MO (ft); 13863' Casing Stru¢tural Conductor .. Surféice h1termèdiate PrQdüction liner' Pet10ratiän Depth'MD (ft): 1~120-12145, 12164-12210. 12275-12315, 12:335-12450, 12520-12610,12665·12725, 12845.12890,13172-13270 Total 'Depth TVe) (ft): . , 0, 129' Length 601' 5.960'" 1'2;416' '13.66S' Suspend U Repair well 0 Pull Tubing 0 !:\ B~/,~:1:, ;31 :;~'~;chm3J:g!B Other W Development Stratig raphic o o , Perforate U WaivarU Stimulate 0 Time £xten$ion 0 Re-enter SU$pende~ Well n 5. Perrn~t to ~I' Numl:Ìer~ Exploratory 0 68-109 ,V Service 121 6. API Number; 50-133-20162-00 ./ 9,VveU Name and Number: G-16 '10, Fleld/F"Qols(5); ,. McArthur River Field Tyonek G and Hømloék PRESENT WELL CONDITION SUMMARY Effective Dept,,'MD (ft):' Effective bepth T\lO (ft): PI~gs (me:asured): 13,482' 10,012' Site 173/4" 1~ 3/6" K-55 611# 9 5/8" N-aO 4Q# 7" N-80 29# Pêrtoration Depth TVD (ft); 9057 -9076. 9090-9124, 9173- 92Ò2, 9217·9300, 9:350-9414, 9465-949'1", 9571·9601, 9783- 9846 Páckers anti SSSV Type~ Saker permanent packer5 12~ Attachments: Description Summary of Proposal 0 Detailéd Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17, f he'rêby certify that the forego(ngis true and correct to the best 01 mÿ knowledge, .'- Contact' q aï _ 7. <'.,~_~ l'1rAFr:. Printed Name c....... ~ ~ Title k ,,\,,\'. ~ . , . ~... ~r~u@..~ ~"'" PN'i-... '-\.("\V\~\-r\«1 .-;P~. ~n,'(" ~~o..\Y\PPL Sl9.l1ature \ "...........r~ "~...., Pho~e ~te \?4?r"f..J,?ooç; Ù . COMMISSION USE ONLY ~ ~. 12/20/2005 Date: , ' , Junk (measl.I,sd): ·IVID Collapse TVO Burst 601' 5,966' 12,416' 13,Sa3' 2,630 3,090 5,7~Q e,160 1,020 1 )540 3,090 7,020 601' 4,568' 9.249' . 10,1'29' Tubing Size: Tubing Grade:· 9.2# N-SO Tubing MD "(ft): 12,805' 31/2" Packer$ and SSSV MD (ft): PacKers at 12,048' and 1,2,750' 13, Wel!' Class a1ftêr proposed w'ork~ Exploratory 0 Development - . 15. Well Status after proposed work: Oil 0 Ga$ 0 WAG 0 GlNJ 0 o Servi¢e o o o Abandoned o o Plugged WINJ W DSPL Conditions of approval: Notify Commissior"l so that a representative may witness Sundry Number: .30 S- - $ 9 () Plug Integmy 0 BOP Test 0 MechanIcal Integrity Te$t 0 Looatlon Clearance 0 Other: \> 't'Cc.rS\...) \-<1. \'£.'-J ~\ '-~ _L_..- \) \ (' \ -k..?:) ~ ,,-..;JIÒ'Ç> C\,o..,,-~~'~'~ ~\.~'~'RBDMS 8FL DEC 2 2 2005 APPROVED BY THE COMMISSION Date: /¡'2-1r ,-of Submit in Duplicate ) ) G-16 Casing Test C~\~ ') -- \")- ( )0 -c <::, Objective: Attempt to locate possible casing leak in well G-16 Minimum 10: Tubing Size: Enp of Tubing: 2.813" @ 11,891' 3 }'2" 11,925' 1. Rig up slickline, pressure test lubricator and run static temperature survey from surface to tubing tail. 2. Return well to injection with injection down the annulus for 24 hours. Do not exceed 500 psi wellhead pressure or 500 BWPD injection rate. 3. Shut-in well and run static temperature survey. 4. Wait 12 hours and run follow-up temperature survey. 5. Return well to injection down the tubing for 4 day trial period. Do not exceed 1,900 psi wellhead injection pressure. 6. Shut well in for 12 hours. 7. Sun static temperature survey from surface to tubing tail. 8. Rig down slickline and leave well shut-in. OF:¡'~lNAL ) ) G-16 Casing Test c....~\~ ') \·~·(~o-~~ Objective: Attempt to locate possible casing leak in well G-16 Minimum 10: Tubing Size: End of Tubing: 2.813" @ 11,891' 3 %" 11,925' 1. Rig up slickline, pressure test lubricator and run static temperature survey from surface to tubing tail. 2. Return well to injection with injection down the annulus for 24 hours. Do not exceed 500 psi wellhead pressure or 500 BWPO injection rate. 3. Shut-in well and run static temperature survey. 4. Wait 12 hours and run follow-up temperature survey. 5. Return well to injection down the tubing for 4 day trial period. Do not exceed 1,900 psi wellhead injection pressure. 6. Shut well in for 12 hours. 7. Sun static temperature survey from surface to tubing tail. 8. Rig down slickline and leave well shut-in. DU~'~ t: l'~,E J.e.", . Casing Test 12-05- Revised ) ') su.~j.ect;..·.·è.'lsi~~·...~·~.st·..·.l.2.-0·5.~...R..~vi.§ed 1f"~111:..· ..·II~;l111Þ.~ft,·..·.·~.t~-ve·.·.(>.'.'·.·.5sal·(U11;b.ert~~n()cal..cQm> ])~~~: W~d,21:Q~c..20ºS.R~:S6:Q6.·+Ø800 . .<;>:tn¡ «Casing Test 12-05- Revised.doc» Tom thanks for the suggested change to the G-16 test procedure. Based on your suggestion, the attached procedure has been revised to start with injection down the annulus. This should give us the best opportunity to locate the possible casing leak. Since the well does not have integrity, it will remain shut-in following the test. Content-Description: Casing Test 12-05- Revised.doc Test 12-05- Revised.doc Content-Type: application/msword Content-Encoding: base64 ~\~ .~~ '0OC..\ '\ c.,. \.0 <:1..~11'-\.\'>\- \o,\~",\,\,-\ 0.., ~C> \-Q. ,,'-\- '\ <... \ Co.. S \'^-- ~ \<co... ~ <y4.~Q:. ¢ r-~~'>L\.J'>~ l.\- <,.\-o.,\-, ~ ~ Oc...... ~~ a,,-'I'-.~ \~"> M....ÙI~e ~~ Stè,,--~~ +~"-- t".~M\i>-~ 0"-- ·\4 --l.J~\I'-.~ X"-.!)~,~ ''''-'\\\Q'', ~O~~ ~\--a -W~\~ LO~ \~ MC\S ~ -\-~ ~<'-~'\Q \ CGf;~~ \ <ï.Þ.. \t-. \ "" ~ \0.. "'- ~ -..)~ \ -.j 'v.... ~ 'v'::> \ '\ ~ \ ~~.. (\ ~ \ \ ~0\ \--Q..' ~ <:1..""'- Q:.~ "- c--... p~ ' a.+- ' \-\L ~~ \.-. <:> t- ~\~, \;:, t\J C \" ~,"-S ßü'1 ù",~'> . Þ>..s ~-0~~ l I:"--,*--~ ~~C) cú. \ I C 4.0~ ~ <; t\:~-.J~S~, A8PN l ~Go~~ 1 of 1 12/20/2005 1 :58 PM ) Chevron .. Steve A. Lambert Reservoir Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7658 Fax 907 263 7847 Email salambert@chevron.com Decem ber 13, 2005 REC·EPJED DEC 1 9 'l005 A\aska Oi\ & Gas Cont, \ifJmm\ssion Anchorl'~¡,? Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 SCANNE[i DEC 2 82005 Determine Location of Tubing and Casing Leak GRAYLING PLATFORM WELL NO. 16 MCARTHUR RIVER FIELD Dear Tom: Unocal is proposing to perform a brief injection test on well G-16 for the purpose of locating a possible casing and tubing leak in the well. Enclosed is form 10-403. Well G-16 was returned to injection on September 27. The well had previously shown communication between the tubing and annulus. After being returned to injection, there were no indications of casing pressure. Attempts to pressure up on the casing and prove casing integrity were unsuccessful. The well was shut-in on October 5. ~.' .. . . ~. " , , t)~0\'ßL ~u't~cJ \~ {-- Following is the proposed procedure for locating th'e casing leak.' , 1. Rig up slickline, pressure test lubricator and run static temp tail. 2. Return well to injection for 4 day trial period. pressure. 3. Shut well in for 12 hours. 4. Sun static temperature surv om surface to tubing tail. 5. Return well to injecti I h injection down the annulus for 24 hours. Do not exceed 500 psi wellhead pres or 500 BWPD injection rate. 6. Shut-in and run static temperature survey. / 7. W' hours and run follow-up temperature survey. 8. ig down slickline and leave well shut-in. Please let me know if you require additional information. ~~x~ Steve Lam bert Enclosure Union Oil Company of California I A Chevron Company http://www.chevron.com REC;::I\/ED ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION DEC 1 9 2005 APPLICATION FOR SUNDRY APPROVALS AIªlk~ Q~I ª GII Cans, C€m'i.'· 20 AAC 25.280 ~ ,,,~hm~n' 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Waiver LJ ;J her ~ Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Numb Union Oil Compnay of California Development 0 Exploratory 0 68-109 3. Address: Stratigraphic 0 Service 0 P.O. Box 196247 Anchorage Alaska, 99519 7. KB Elevation (ft): Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 10,129' Length Effective Depth MD (ft): 13,482' Effective Depth TVD (ft): 10,012' Junk (measured): 9. Well Name and Number: 99' G-16 10. Field/Pools(s): McArthur River Field Tyonek G and H PRESENT WELL CONDITION SUMMARY 8. Property Designation: ADL 17594 11. Total Depth MD (ft): 13663' Size I'D ~ 601' ;0 01' 5,960' t{) 4,568' 12,416' /) \- ì 9,249' ~,V 10129' Tubing SiZ~ J TUbin~ Grade ~/2" fý < ~æ 2,630 3,090 5,750 8,160 1,020 1,540 3,090 7,020 MD Burst Collapse 601' 5,960' 12,416' 13,663' 173/4" 133/8" K-55 61 # 95/8" N-80 40# 7" N-80 29# Plug Integrity 0 Perforation Depth TVD (ft): 9057-9076,9090-9124,9173- 9202,9217-9300,9350-9414, 9465-9491,9571-9601,9783- 9846 9.2# N-80 Tubing MD (ft): 12,805' Perforation Depth MD (ft): 12120-12145,12164-12210, 12275-12315,12335-12450, 12520-12610,12685-12725, 12845-12890, 13172-13270 Packers and SSSV Type: i...? Baker permanent packers 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: Packers and SSSV MD (ft): Packers at 12,048' and 12,750' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Service 0 16. Verbal Approval: Date: Oil 0 WAG 0 Gas D GINJ D Plugged D WINJ 0 Abandoned D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and c ect tê the best of my knowledge. Printed Name Title Signature Contact Date COMMISSION USE ONLY Conditions of approval: Notify Com ssion so that a representative may witness Sundry Number: Mechanical Integrity Test 0 Location Clearance 0 Other: Subsequent For· I Approved by: Form 10-403 Revised 07/2005 COMMISSIONER APPROVED BY THE COMMISSION Date: Submit in Duplicate • J - _ _, i, is ~. ALASS-A OIL A1QD GAS COI~ISER~ATIOI~T COrIl~IISSIOIQ • FRANK H. MURKOWSK/, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ~' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 5.005 NIr. Steve Lambert Reservoir Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 ~~~ ~A~ a ~ 2~os RE: Trading Bay Unit G-16 [aka Grayling 16] (PTD 168-109} Request for Administrative Approval AIO 5 Dear Mr. Lambert: Per Rule 9 of Area Injection Order ("AIO") 005, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska ("Unocal")'s request for administrative approval for water injection in the subject well. Based upon the information provided to us, AOGCC finds the following: 1. This well was originally reported to have experienced tubing x inner annulus ("T x IA") communication in August 1997. 2. A workover was performed in March 1998 with the well passing the standard MIT. 3. Despite the repair effected by the workover, the IA pressure gradually increased indicating continued communication. 4. On June 5, 1998 Unocal applied by letter to keep the well in operation with known T x IA communication. Unocal's request was approved. 5. Unocal has been operating TBU G-16 in accord with the agreement of June 5, 1998, however current Commission policy is that such authorizations require an Administrative Approval. 6. While operating the well, Unocal has performed temperature surveys to demon- strate that injected fluids are being placed in the intended formations and report- ing daily observations of rate and well pressures. The most recent temperature survey was conducted on June 25, 2005. 7. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any further pressure integrity loss. 8. At this time, Unocal is not proposing to repair the well to restore full integrity. Ntr. Steve Lambert September 7, 2005 Page 2 of 2 9. An aquifer exemption is in effect below Cook Inlet for Trading Bay Unit (McArthur River Field) [40 CFR 1~7.102(b)(2)(ii).] Based on analysis of the submitted information, the Commission concludes that TBU G- 16 exhibits two competent barriers to release of well pressure. Accordingly, the Com- mission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Trading Bay Unit G-16 [aka Grayling 16] is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing,'inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and ~. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after w°ritten notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered 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. A person may not appeal a Com fission decision to Superior Court unless rehearing has been requested. Alaska and dated September 7, 2005. N ~~p, uti.,JA`~r~ ~~ y~ ~ jJ ~ ;' 1 : I ~l ~ ,.+C~',l":t's.~ fie .~ Y ,I 4~. _~ ~O ~_. ~ = ~ ~ S _ -~ "~.~ ~_... S .. •, l I~anie,VT`. Seamount, Jr Commissioner ~'~~ """ Cathy , . Foerster Commissioner ) ) Unocal Alaska Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 UNOCALe .,' . :. .. , ...~ ~" ',- ~,.., ...., ..I,..... Date: September 2,2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. ihAve., Suite #100 Anchorage, AK 99501-3539 Attn: Tom Maunder 1\ i'f-, Loa ç 1-\ \ \...)....~ .. Administrative Approval Request Well No. G-16 Injector Grayling Platform McArthur River Field Dear Chair Norman, (.~ E Ii) ~} (,'! ~) Ir t.,1! í,)' [ ~î Unocal requests administrative approval under Area Injection Order 5, Rule 9 for the continuation of injection of non-hazardous Class /I fluids for the Grayling Platform Well No. G-16 Injector (Permit # 68-109) in McArthur River Fie,ld. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). Well G-16 was drilled and completed as a producer in 1969. The well was worked over and converted to an injector in June 1974. In 1978 the well was worked over to repair a hole in the casing at 12,596' (The hole was located below the packer within the "G" zone.). In 1986 the well was worked over to convert the well to a dual "G" zone and Hemlock injector. In 1998 the well was again worked over to repair tubing leaks and was converted to a single string "G" zone and Hemlock injector. The well was· shut-in in June of 2005 due to apparent communication between the tubing and casing. A temperature survey run after the shut-in confirmed that all of the injected fluid was exiting at the perforations. Following the return of this well to injection, Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. ) ") Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7658 or Larry Greenstein at 263-7661. cc: MIT book Well File Sincerely, Steve Lambert p;;[cJI UNOCALe RKB to TBG Head = 41,35' ¿ ~ I '\....j DV Collar @ 6172' 1 ~~% 2 3· · .. 5 G-1 G-2 - G-3 12.416'¿ ~ G-4 - G-5 - G-6 12,780' = HB-1 - ~ HB-2 .... n H B-3 13,154' HB-4 - ~ ~ / ~ ETD = 13,384' TD = 13,663" KB ELEV = 99' MAX ANGLE = 48.49 @ 11,067' G-16 Schm 3-25-98 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 17-3/4" ,312 wall Weld Surf. 601 ' 13-3/8" 61 K-55 Seal Lock 12.515 Surf: 5960' 9-5/8" 47 P-110 Butt 8.681 10,680' 12,416 9-5/8" 47 N-80 Butt 8.681 8503' 10,680' 9-5/8" 43,5 N-80 Butt 8,755 6296' 8503' 9-5/8" 40 N-80 Butt 8.835 4009' 6296' 9-5/8" 43.5 N-80 Butt 8.755 54' 4009' 9-5/8" 47 N-80 Butt 8.681 Surf: 54' 7" 29 P-110 Butt 6.184 11,345' 13,663 ' 7" 29 N-80 Butt 6.184 Surf: 11,345' 7" DV Collar 6172' 6174' Tubing: 3-1/2" 9.3 L-80 EUE. AB Mod 2.992" 0' 6508' 3- 1/2" 9.3 L-80 ST-L 2,992" 6508' 11,834' ) NO. 4 DeDth 41.35" : i .H-+2 I i .S'¡}' 11.8../8" ¡ i ,[\9 i 11,915' ) Trading Bay Unit WeB # G-16 Actual Recompletion(3/25/98) CMT 2350 sx 1000 sx 1300 sx JEWELRY DETAIL Item 3-1/2" CIW DCB Tubing Hanger 3-1/2" Butt x 3-1/2" EUE Baker K-22 Anchor Tubing Seal Assembly Baker Model "84SAB40x32" Penn Pkr, 3.25" ID Baker Mill out Extension Baker "X": nipple profile Ball Seat Sub ID 3.25 3.25 3.75 2,813" 2,992" Bad Casing from 12,780 to 13,154'. Squeezed with 300sx cement on 4/3/78 FISH Baker Model DB Packer with seal bore extension Cmt Retainer Junked Pkr Cmt Retainer Zone G-1 G-2 G-3 G-4 G-5 G-6 HB-1 HB-2 HB-2 HB-3 HB-4 Top 12,120' 12,164' 12,275' 12,335' 12,520' 12,685' 12,845' 12,904' 13,005' 13,108' 13,172' Btm 12,145' 12,210' 12,315' 12,450' 12,610' 12, 725' 12,890' 12,985' 13,088' 13,142' 13,270' PERFORATION DATA Accum Last SPF Perf Date 12 4125/87 12 4/25/87 12 4/25/87 12 4/25/87 12 4/25/87 12 4/25/87 16 4125/87 6/14/74 6/14174 6/14174 4125/87 Amt 25' 46' 40' 115' 90' 40' 45' 81' 83' 34' 98' 20 3/23/98 6/18/74 3/30/78 4/2/78 @13,384' @13,462' @13,482' @13,482' Present Condition Open f/lnjection Open f/lnjection Open f/lnjection Open f/lnjection Open f/lnjection Open f/lnjection Open f/lnjection Cmt Sqz'd Cmt Sqz'd Cmt Sqz'd Open f/lnjection REVISED: 1115/97 - 4000 ...... C!) ~ - .. C > 5000 l- I .c ...... c. C!) "I C 6000 ) IUnocal well: G-1 5 Field: GrayHng o o Pressure (psia) 1500 2000 2500 3000 3500 4000 4500 500 1000 1000 ~. '···..~::·"I,"..._.., ...j ...,~ Pressure-Temperature Profile 1, 'GOÎJu1g]Uj tJoile T\/D 2000 3000 -. ..' -... - ., '-~"-"'- 7000 ". I- I 8000 9000 ! "_.ç.".... r· , I .. I 60 110 120 --I" - -.-- - I 70 10000 40 50 80 90 100 Temperature (Deg. F) 1- Pressure 16-25-20051 5000 5500 ~l.i. :,.1 · ,.- ., ,,~'. , · 'ì~' I .' "1'"'" ,'.{. - -:..Ii'-- :.,)~' :,', '. .~" ~ · .!~., . I' , , 'I~" '" .. 'if" .. · .!~".. "I~' ,. ì, . ..:1- . "I)~"~ :,(:- .. :¡, .j.... .. !,t- ! ,;... .. .. 130 140 150 Perfs -17 3/4" -133/8" =-95/8" -7" -TBG -Temperature I Report date: 9/2/2005 ) GRAYLING PLATFORM API # 50-733-20162-00 TBUG-16 WELL HISTORY LAST WORK: 2/15/99 Date Action 1969 1/6 Spud well 2/2 Twisted off @ 1,7261 while drilling @ 10,095.' Recovered fish to 9,909.1 Spot cement and side track well @ 9,700. I 2/6 Twisted off @ 1,7231 while back reaming out of hole with BTM of hole @ 9,733.' Recovered fish to 9,592.1 Spot cement and side tracked well @ 9,399.' 2/28 Cored F/12,258'-12,277' 3/3 Set 9 5/811 casing @ 12,416'and cemented same 3/12 Parted pipe @ 1,7311 while drilling @ 13,128.1 Recovered fish to 12,825.' Spot cement and side track well @ 12,580.1 3/24 Twisted off @ 1,7111 while reaming to Btm @ 13,661.1 Recovered fish to 12,658.1 Spot cement and side track well @ 12,552.' 5/9 TO well @ 13,6841 5/15 Perforated 4HPF in 711 casing with 3 1/211 guns F/: 12,844'-12,884' 12,904'-12,9851 13,005'-13,088' 13,1081-13,142' 13,172'-13,2701 7/7 Pressure buildup: 1,917/1,802 60/0 water cut k=48.3 md Ps=3,094 psi 1970 3/6 Profile: Bench HB#1 HB#2 HB#3 HB#4 %Oil 15.7 25.5 19.6 39.2 %Water 31 ) ) 3/9 Profile: Bench HB#1 HB#2 HB#3 HB#4 %Oil 6.6 14.0 43.4 36.0 %Water 1972 3/16 Gas lift survey 551/110 80% water cut Ps=3,130 psi Pwf=2,001 psi 8/31 Workover -isolated benches #3 & 4 by setting cmt RET @ 13,093' & cement on top to PBTD of 13,087.1, 1973 4/14 Gas lift survey 294/250 BPD 15% water cut Ps=3,500 psi Pwf=675 psi 9/7 Gas lift survey 494/300 BPD 39% water cut P s=4,050 psi Pwf=3,038 psi 8/11 Reperforated: 12,8601-12,8801 12,9921_12,966' 13,0051-13,0351 10/1 Gas lift survey 650/276 BPD 42.5% water cut P s=4,OOO psi Pwf=2,696 psi 1974 1/22 Gas lift survey 984/246 BPD 750/0 water cut Ps=4,OOO psi Pwf=2,240 psi 6/18 FISH - Left cmt. ret. fish @ 13,462'. 6/21 Workover converted \/\fell to an injector, squeezed benches -7/15 #1-3 with cement. Fracture stimulate bench #4 perforations F/13, 172'-13,2701 (4" guns) 13,500 Ibs (20-40 sand?) @ 8,900 psi max. pressure (YF 60 NC frac. fluid) 10/3 Injection profile: Found hole in tubing @ 12,8621 1978 2/29 Workover squeezed hole in 1" casing F/12,5961-13,154' 3/30 FISH - Left junk pkr. fish @ 13,482'. 4/2 FISH - Left cmt. ret. fish @ 13,482'. ) ) 9/27 Profile: Bench %Oil %Water HB#1 0 HB#2 40 HB#3 11 HB#4 49 1980 11/22 Profile: Bench %Oil %Water HB#1 7 HB#2 53 HB#3 9 HB#4 31 1981 1/21 Reperf'd HB1 F/ 12,845'-12,890' & HB4 F/13, 172'-13,2701 1 0/27 Profile: Bench HB#1 HB#2 HB#3 HB#4 %Oil 8 40 33 19 %Water 1986 1 0/15 AFE to convert to a dualllGII Zone & Hemlock injector 1987 4/25 Perforate 12.6 HPF G-1 121201-12145' G-2 12164'-122101 G-3 12275'-123151 G-4 12335'-12450' G-5 125201-12610' G-6 12685'-127251 HB-1 12845'-128901 HB-4 13172'-13270' 5/2 Acidized w/1680 gal 5%HCI and 35,600 gal 12-3% mud acid with diverters. 5/8 Ran 3-1/211, 9.2# & 2-7/811, 6.4#, N-80 tubing w/Seal-Iock & IPC. Landed tubing on new Cameron stainless steel tubing hanger. ) 1988 Injection Profile: 11/22 G-Zone Benches Perforations 0/0 of 1.965 BWPD G1 12,120'-145' 9 G2 12,1641-210' 0 G3 12,2751-3151 0 G4 12,335'-450' 25 G5 12,520'-610' 33 G6 12,6851-725' 33 Hemlock Benches Perforations 0/0 of 5.045 BWPD B1 12,845'-8901 0 12,9041-9851 sqz'd 42 B2 13,005'-0881 sqz'd 17 B3 13,108'-1421 sqz'd 8 B4 13,172'-2701 33 1995 6/9 GR - RIH w/2.1875 gauge ring. Tagged @ 13,436 RKB. 1996 1997 8/3 GR - RIH w/2.72" gauge ring, Tagged XO @ 12,079' WLM (12,086' MD). RIH w/2.23" gauge ring. Tagged obstruction @ 12,220' WLM. RIH w/2.25" LIB & tagged obstruction @ 12,220' WLM (Showed deep gouges on side & smaller in middle) . 1998 1/5-6 WL - Set 2.75" PX plug in XA sleeve at 12,042' KB to test casing above packer. Known communication form tubing to casing Set 2.75" PX plug in XA sleeve at 12,042' KB to test casing above packer. Known communication form tubing to casing. SET PX PLUG, SET PX PRONG, PRESSURE TEST TUBING AND CASING, PULL PX PRONG; PULL PX PLUG. Pressured tubing to 2,450psi using injection header, very slow build up on 7" casing from 700 psi to 800 psi. Maintained 2,450psi injection pressure on tubing and pressured 7' casing To 2,400psi, bled to 1,100 psi in 3 minutes. Attempted to repressure 7" casing several times with same results, no pressure build up on 7" x 9 5/8" casing annulus. Pressured tubing and 7" casing 0 2,400psi, bled to 750psi tubing and 750 psi casing in 30 minutes. Suspend operations 1/28 SR - Ran TDT-WFL Survey. Interpretation Findings: The sliding sleeve @ 12,042' is leaking. The packer @ 12,073' is not leaking. A tubing leak exists between 1,500' & 3,000'. 3/13 WL - Tried to get X-over sub to seal. Could not '... 3/16-27 3/23 3/25 9/4 1999 1/5-6 2/15 2002 10/1 2004 12/1-31 2005 1/30 2/19 6/6 6/24 ) ) PS - Well work was required on G-16 water injector to repair tubing to casing communication and to further investigate if there was a hole in the tubing above the uppermost packer. The existing completion was recovered which indicated leaks in the production tubing above the uppermost packer and parted tubing above the lower packer. Following a clean out run to well ETD a RTTS was utilized to test the casing integrity above the planned setting depth of the single injection packer. Pressure tests were made at 11,400' and 11,850' with the following results: Depth 11 ,400' 11,850' Initial Pressure 3500 psi 3740 psi Final Pressure 3500 psi 3688 psi Time 15 min 30 min Confirmed casing integrity above 11,400'. Following this the well was re- completed as a 3-1/2" single injector with the injection packer set at 11 ,843'. Subsequently an MIT was conducted (attached) which indicated mechanical integrity. The well was put back on injection on 3/27 March 1998. FISH - Left Baker Model "DB" Pkr. with seal bore extension @ 13,384'. WO - Ran gauge ring to make sure tubing is not over tightened. RIH with 2.865" GR to 2,000 RKB. POOH Stand by for drilling to run 2,000' of tubing. RIH with 2.865" GR to 1,320' RKB. Set down, beat down, could not pass. Beat up for 15 min. Come free. POOH Stand by for drilling to pull out tubing. Have two over tighten pieces of tubing. Run new Tubing. RIH with 2.865" GR to 1,000' RKB. POOH Stand by for drilling to run 1,000' of tubing. RIH with 2.865" GR to 1,000' RKB. POOH GR - RIH wi 2.70" qauge rinQ to 13,330', POOH. WL - Scratched XA sleeve, Set PX Plug in sleeve and test for communication. TAG - RIH wi 2.70" Qauge rinq to fill @ 13,225' KB, POOH. Standard MIT witnessed and passed by state inspector. Waterflood shut-in due to lack of fuel gas. Waterflood returned to service. Standard MIT witnessed and passed by state inspector. Well shut-in due to tbg.-csg. communication. Ran 2.5" GR to 13,100'. Tagged fill. Ran static temp and pressure survey. 1,000 2,000 3,000 4,000 5,000 6,000 - ê > I- ::; 7,000 Q. G) o 8,000 11 ,000 12,000 - l " 13,000 - "-- G-16 Maximum Allowable Operating Pressure Graph o 2,000 3,000 Pressure (PSI) 4,000 5,000 6,000 7,000 8,000 1,000 9,000 10,000 SU1""'le!!h;mc.e Thresholds ~6~~~~;~;:~;:~~es~ ings CSG?RESS = CS~PR=SS CSGPRESS2 = C;;?RESS2 CSG?RESS3 = C~FRESS3 CSG?RESS4 = C~?REs.....'4 CSG?RESS5 = C~FqESS5 CSG?R2SS6 = C3:;PRESS:3 Casing Details Production Segmed Production Stgcoll? Production Segmept No Data Production Segme.t Production fk:ollar Production Segmeot Production Floatsh .e Intermediate Segment Intermediate Segl11i!nt Intermediate Segment Intermediate Segrrent Intermediate Segment ¡ate Segrœnt ~. C<Bing Gond ,!..r~~~'_..~ = ð-':=:"f = '!!~~".:,:,:: = ~?'5 A':=õ! = 2X .~¡2r:1¡r:~ = Als::! = If!a~é\:",,;c = ~:5 .~_'=:t = 2C') eight Grade Yield Top N-80 8160.0 360 61716 N-80 8160 0 61739 113450 11220.0113454 136153 11220.013617.0 13660.9 9440.0 15.0 63270 53.8 5745.0 4009.4 6327.0 6295.9 68700 8.503.3 9440.0 10680.5 3090,0 360 l 36.0 600.0 360 Size 7 7 7 7 7 7 7 7 9.625 47 9.625 43.5 9.625 40 9625 43.5 9.625 47 9625 47 13.375 61 17.75 17.75 26 29 ..ters I Assumptions 9 ~d @ 7m<. of nomini:ll with flu}d YlCight of 0 3 iUff: i~ yield @ 45% of nominal Yoith fluid weight of O. 33 #11ft Surface casmg )1ieI. @45% of nominal with fluid weight of 0.433 Fracture gradient Program attempts '> API : 507332016.00 Perm~: 1681090 gi~~I~~~;:~J~~~;n r~¿~blíshed sources where specifical~s are known If specifications are unknown then values are the lowest value of probabJe materiais 14,000 (;>TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 fL MD 0-' , \ \ \ \ \ \\ ;\~\. !. \ [ \ '\ 1\ . LL \ \ \ \ \ \ '\ \ \ \ \ \ \ \ \ \ Variable Definitions \ I ~~p ==R;:i:"~::S;::Sure \~ SF = Safety Factor (10% for woriting annulus; 45% for outer annuli} HP ::: Internal Fluid Hydraurtc Pressure .... 10,000 __ _~.!;P_=.~a~-"-"'.~I>Ie_surfaceW<>l1<ing pr,=,-ure \ 9,000 Graphical calcul~ion method Inside pressure potential == OutsKte pressure containment Therefore HP + MASP = RP + (GYP' SF) Rearranging MASP = RP +'(GYP' SF) - HP -Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/It -Production CYP @ 70% -Outside Containment for Production casing -MASP (production casing) -Intermediate CYP @ 45% -Outside Containment for Intermediate casing -MASP (Intermediate casing) -Suñace GYP @ 45% - Outside Containment for Surface casing - MASP (Suñace casing) <Þ Current Pressure Readings ~ \ \ Graphical Casing Pressure Analysis ver 22y.xls Bottom 61716 6173.9 113450 113454 136153 136170 13660.9 136633 53.8 4009,4 62959 8.503.3 106805 124160 59600 6000 601.0 3760 \ "I~""\I!I,o~ {fU \~<\, ru '~ I)~ :1,', ~ E',,',~"~,~ .1 r :1 ,\~~1 ''''-:::¡ ,!IL 'I f';j U ) AT~ASIiA OIL AND GAS CONSERVATION CO.MMISSION Mr. Steve Lambert Reservoir Engineer UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: TBU G-16 [Grayling 16]--168-109 Sundry Number: 305-153 Dear Mr. Lambert: i5(~ANNED AUG ~~ 0 2005 ) FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ""o¡c,~ >lðiJ. " Pursuant to the discussions held in the Informal Review regarding the mechanical condition of TBU G- 16, your sundry application is being returned marked "not used". With the well shut-in, Unocal was able to accomplish planned diagnostics regarding the well's mechanical condition without placing the well in operation. If it is Unocal's intent to return the well to operation without restoring complete integrity, an application for Administrative Approval under the applicable area injection order [AIO 5] should be made. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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 'ay'f the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision Sup ior Court unless rehearing has been requested. BY ORDER O~ JRE COMMISSION DA TED this ~ay of August 2005 Enel. 1. Type of Request: -) STATE OF ALASKA ) ALAvKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: P.O. Box 196247 Anchorage, Alaska 99519 7. KB Elevation (ft): 99' Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: 8. Property Designation: ADL 17594 11. Total Depth MD (ft): 13,663' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 12120-12145, 12164-12210, 12275-12315,12335-12450, 12520-12610, 12685-12725, 12,845-12890,13172-13270 Packers and SSSV Type: Baker permanent packer Total Depth TVD (ft): 10,129' Length 601' 5,960' 12,416' 13,663' Suspend 0 Repair well 0 Pull Tubing 0 Development Stratigraphic o o Perforate 0 Waiver 0 Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Other 0 Exploratory 0 Service 0 68-109 6. API Number: 50-733-20162-00 9. Well Name and Number: G-16 10. Field/Pools(s): McArthur River Field Tyonek G and Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): 13,482' Effective Depth TVD (ft): 10,012' Size \ 601' 5,960 173/4" 133/8" K-55 61# 95/8" N-80 40# 7" N-80 29# Perforation Depth TVD (ft): 9057-9076,9090-9124,9173- 9202,9217-9300,9350-9414, 9465-9491,9571-9601,9783- 9846 \ ~'\ BOP Test 0 Approved by: Form 1 0-403 Revised 11/2004 12. Attachments: Description Summary of ProPL?al ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Plugs (measured): Junk (measured): Burst Collapse 601' 4,568' 9,249' 10,129' 2,630 3,090 5,750 8,160 1,020 1,540 3,090 7,020 Signature Tubing Grade: 9.2# N-80 Tubing MD (ft): 12,805' o Service 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Abandoned 0 WDSPL 0 Phone COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 Other: Subsequent Form Required: Mechanical Integrity Test 0 Contact Date Sundry Number: 30'5-1 ~ Location Clearance 0 RBDMS BFL AUG 2 4 2n05 o R iCCTi\}Nt\ L APPROVED BY THE COMMISSION Date: Submit in Duplicate RE: TBU 0-16 ) -) ,. Subject: RE: TBU G-16 From: "Lambert, Steve A" <salambert@unoca1.com> Date: Fri, 08 Ju12005 03:04:06 +0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> We tried to pressure up the csg and the pressure would not increase above 1650 psi. When they stopped the pump, the pressure bled off quickly so we definitely have communication between the tubing and casing. I am anxious to see what the temperature survey indicates. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, July 07, 2005 10:52 AM To: Lambert, Steve A Cc: Greenstein, Larry P Subject: Re: TBU G-16 Steve, Any progress on the MIT or other resolution of this matter?? Tom Lambert, Steve A wrote: Tom I will schedule an MIT for this well. It will give us a better understanding of how to move forward with this well. -----Original Message----- From: Lambert, Steve A Sent: Thursday, June 23, 2005 11:40 AM To: 'Thomas Maunder' Subject: RE: TBU G-16 It seems like a reasonable approach to take. Let me discuss with my boss and get back to you. -----Original Message----- From: Thomas Maunder [mai.lto:tom maunder@admi.n.state.ak.us] S en t: Thur s da y , June 2 3·'~····"·"2··O"Õ'5····m9";·28·m"AM··'·.."··"···m.....mm..mmm.mmm..mmm.m·.m·m·..m··'.·.·...,,···,···,..·,..·..·..·.. To: Lambert, Steve A Subject: Re: TBU G-16 Steve, The pressure plot indicates that there is about a 500 psi differential from tubing to IA. It appears that the prior differential was about double this. As I recall, when Lou witnessed the recent MIT out there, he had sufficient pressure applied to the IA to establish a 500 psi delta from IA to tubing and I understand this was successful. Is is possible to perform another MIT on the well?? Doing any testing is Unocal's decision, however if a MIT is attempted it would seem prudent to apply the pressure slowly and evaluate the pressure response at chosen pressure values (ie 500 psi over tubing pressure, 1000 over tubing pressure, etc). I look forward to your response. Tom Maunder, PE AOGCC Lambert, Steve A wrote: I have attached the pressure data for June. We bled off the casing pressure after we shut the well in and we have not seen any increase in 1 0[2 7/12/2005 8:46 AM RE: TBU G-16 ') ) casing pressure even though we have pressure on the tubing. In answer to your question there does not seem to be complete communication. I am not sure if we could pass an MIT today. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] S en t: Thursday, June 2'3··';.........:;iö..õ"5·......8..·~·Õ5......AM'·....·.....·.................·......................,.................................,.....................,..... To: Steve Lambert Subject: TBU G-16 Steve, I received the sundry. Based on the conversation with Dave, Jeff and yourself yesterday I have a couple of questions. 1. Since the well was SI, how have the pressures behaved?? 2. Does the pressure behavior indicate that that the tubing and IA are isolated?? Thanks I Tom Maunder, PE AOGCC 20f2 7/12/20058:46 AM MEMORANDUM TO: Jim Regg v~(¿."l'"' Z( üt-( í) Ç' P.I. Supervisor f-.ttl FROM: Lou Grimaldi Petroleum Inspector Well Name: TRADING BAY UNIT G-16 Insp Num: mitLG050220174851 ReI Insp Num: ) State of Alaska ) l~?) -{DC¡ Reviewed By: P.I. Suprv ~-r:&-- Comm Inspector Name: Lou Grimaldi Inspection Date: 2/19/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well G-16 Type Inj. P TVD 8833 IA 1750 2300 2290 2290 I P.T. 1681090 TypeTest SPT Test psi 2208.25 OA 210 210 210 210 Interval 4YRTST P/F P Tubing 3250 3250 3250 3250 Notes: Good test. Casing liquid packed. Tuesday, February 22,2005 Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 22, 2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA G-16 TRADING BAY UNIT G-16 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-733-20162-00-00 Permit Number: 168-109-0 ~ M r,p "\i "1 2DGS SCANNEC nl.l-\." -- _c. - Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test \ b% -' l O~ (Y' \ \p Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us greensteinlp@unocal.com; trodriguez@unocal.com OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Well G-5RD Type Inj. P.T.D. 198-120 Type test Notes: Well G-16 Type Inj. P.T.D. 168-109 Type test Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 Type Inj. Type test Type Inj. Type test Type Inj. Type test Unocal Alaska McArthur River Field I TBU I Grayling Platform 02/19/05 David Myers 1 Charles Chezik Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. S TVD 8,875' Tubing 3,100 3,100 3,100 3,100 Interval 4 P Test psi 2219 Casing 410 2,280 2,260 2,260 P/F P OA 156 165 165 165 S TVD 8,833' Tubing 3,250 3,250 3,250 3,250 Interval 4 P Test psi 2208 Casing 1,750 2,300 2,290 2,290 P/F P OA 210 210 210 210 TVD Tubing Interval Test psi Casing P/F TVD Tubing Interval Test psi Casing P/F TVD Tubing Interval Test psi Casing P/F TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) -~C' .AN' -",iE' -'i"'} FEB 2. ~ 200~ \1.0.~ ,n. .. ~", J."".:' ,~o ~ MIT_Grayling- 02-19-05.xls MEMORANDUM TO: Camille O. Taylor Chair THRU: Tom Maunder P.I. Supervisor ~.j~_-, FROM: John Crisp Petroleum Inspector' State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 1, 2002 SUBJECT: Mechanical integrity Tests Unocal Trading Bay Unit MC, Arthur River Field Grayling Platform NON- CONFIDENTI,.A, L ' Packer Depth Pretest Initial 15 Min. 30 Min. W,ellI 'G'~SRD [Typelnj.! 'S' I T.V.D. l' '8875 i Tubin~ll 3400 I 3400I 3~oo I'3400IIIntervall 4 P.T.D.i 1981200 ]~ypete~tl' P ' i,TestPs!l,2400I ,CasingI 760 I 24o0 I ~z,~oo I' ,2,00 IPIEI Notes: OA pressure 70 psi. · wei~! G-~S I Type ~nj. I s ! Y'V'D' I ~8'33 I'TubJn; I 3250 I ~250 I 3250'}' 3250 I~ht~a~l 4 P.T.D.I 16810'gP.,lTypet,estl 'P ITestpsil 24,50 ICasing! 1900I 245ol 2425I 2,425I P/F I P Notes: OA pressure 310 We,I 9-19 ITypei.nj.I s I T.V.D. I ~s "lT'Ubin~l 3200 I '3200 I 3200' ! '3~00 II~tervall 4 'P,.'T.D.I 1690170 IType{~S~l , P' I Test psi i", 25oo 'l Casi~gl 640 I 25°°1 2500 [,2500 I P/i: I Notes: OA pressure 125 - 210 during pressure test. . , , We,I (~-~z2 ImYpe~nJ.i S'I T.V.D. I S~s2'i~ub~.gl 3~00'1 3~00 i 3~bo I 3~00 i~nterva~l 4 P.7-D-I. 1750!,~) Imypetes.t,I ' P, ,' I~e~.~ll a~s0, ,I casir~g.I .6~,b l. 2.355 ,I '2350 I 235°"! p/F iNotes: OA pressure 180 psi. - 300 during pressure test. , We,I G-231~D I~.e~,i.i" S '! ~-~.~-I ~5~ I~'ubingl 3400 I ~00 I 3400 I 3400 I~nterva~l 4 P.T.D.I 179014O Imypetestl P Imestpsil 2300 I CasingI 560 I 23001 2300 I 23001 P/F I , Notes: oa pressure 86 psi. ' ' , ..... Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval i= Initial Test 4= Four Year Cycle V= Required byVariance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Kenai Alaska 09-30-02 t° be available to travel to the Grayling Platform ~ 0630 hrs. 10-01-02. Testing went well w/Water Flood Operator Davld L. Meyers conducting tests in a safe & efficient manner. No failures were witnessed. All OA pressures were observed & recorded during tests. With no permafrost concerns, all tests utilized filtered Inlet water for test fluids. M.I.T.'s performed: _5 Attachments: Number of Failures: Total Time during tests: 4 bm. ,.c,c; MIT report form 5/12/00 L.G. MIT Grayling Pit. 10*01-02jc.xis 10/912002 - J~n, I~, ZUIJU U:4/PM _UNOCAL ~ :. AL ,or; CONSERVATION C,.,J VllSS vp, l REPOR1 ,.JF SUNDRY WELL OPER., riONS "~":-"bperationS'~'~;iji': ........ operation shutd,3v~r~'i ....... Stimulate: ............. ~ i['~:~i'lq~i="-=' .... Perforate: ..................................... ,,.~U![,tubing: Alter casin~: Re, air well: X Other: ..... "~"~ame of operator 5. Type of We(l: ~, Datum elevation (DF or Union OII Go~any of California (UHOCAL) Development: 99' te.~.L feet "'~:'"~'~r~ ..... ' .............. ;xploratoW: ~ '~'. Unit or prO"e~y Straagraphic: ~,0. ~ox 196247, Anchorage, Alaska Sewi~: X Tra~lng Ba~ Unit ~. Location of well at suvaco .... 8. ~ell number 187g' FSL, 1381' FEL, $e~ 2g, TgN,R13W, SM (Oondu~or 4g, Leg 2) TBUS G-18 At top of productive inte~al '~, Pe~it number/approval number 977' FSL~617' ~L, Sec 2~, TgN, R13W, SM 6~109 At effective ~epth I0, APl number 3~' FSL, 1403' ~, See 27, TgN, R13W, SM 50-1 ~-20162~0 At total depth 11, Fleld/Pooi 258' FSL, 1507'...~.~, Sec 27, TgN, R13W, SM ........ M~hur River Fletd 12, Present well c°~dltlon summa~ Total depth: measured 13,663' feet Ptug~ (measured) true veAi~l ' 10,129' feet E~ct[ve depth: measured 13,384' feet Junk (measura~) MilLed Out Baker Model D ~acker at t 3,3~4' true vestal 9,917' feat Casing Length Size Cemented Measured depth Tree ve~lcal depth Stru~ural ~76' 26" Driven ~76' 376' Condu~or 601' 17-3/4" 750 sx SOl' 601' Suffa~ 5,960' 13-3/8" 2~ ex 5,960' 4,568' I nte~ed late 12,416' g-518" 1000 sx 12,416' 9,24g' P~du~ion 13,863' 7" 1 ~00 sx 1 ~,~6~' 10,1 Liner ~e~mtion ~epth: meaau~ (See A~achme~t) true Tubing (size, grade, and reassume depth) 3-112" L-80 EUE Mod g,3 i~ at 3.1/2" L-80 ST.L g.~ Ibl~ et 11,8~' Pa~ers and SSSV (~pe and measured depth) Baker Model 84SAB40~2 Pe~anent pa~ker set at 11,843' , Treatment de~flptlon Including volumes Used and final pmesure ........ ~.. c'.nns. ~ommi~ion 14." Reomaenffitlve Dally Averaae Pr.~'~Jn~~~ 6300 8PD laS0 psi ~'t 50 p~i Prior to well o~mtlon (1/28/98) Subsequent to operation (3128198) .................. 600~p....... 1000 pal (maintatne~) ~00 1~"~' A~men~': , 16. S[atus of ~11 class~tion CoDiea of L~s and Suweys Daily R~)o~ of Well ~pe~tions; ~ ............... Off: , Gas: Suspended; So,ice; Wator Injector... ~, I hereby ~l~ that the foregoing is true and corre~ to the best of my knowledge: ~ .. _.m . ,-: '"~' ' 'Form 10.404 Rev 00/15/{18 SUt~MIT IN DUPLICATE Jan, 6, 2000 6'47PM UNOCAL CORP, N0.ObUU Grayling G-t6 Summary of Operations Well work was required on G- 16 water injector to repair tubing to casing communication and to further investigate if there was a hole in the tubing above the uppermost packer. The existing completion was recovered which indicated leaks in the production tubing above the uppermost packer and parted tubing above the lower packer, Following a clean · well E a KTT was utilized t,~_t.¢ ,~.~ ~.i,,~, ;.t~..~-, oh~,va the ~larmed out mn to ~ S · sctl;mg dep~ of the sm lem ectton packcr~ P~ess~e tests were made at I t ,400' and---/ 1.850' with the following results: , ' ~ '_ ~ ~ .- . . .... Depth Initial Pressure Final Pressure Time 11,400' 3500 psi 3500 psi 15 rain 11,850' 3740 psi 3688 psi 30 rain Following this the well was re-completed as a 3-1/2" single injector with the injection packer s~t at 11,843'. Subsequently a MIT was conducted (attached) which indicated mechanical integrity. The well was put back on injection on 327 March I998. Jan, 6, 2000 6'47PM RKB to TBQ Heed ' 41,35' G-1 G-2 G-3 15,154' G,,4 __. G-5 HE-1 HE-3 HE-4 ETD · 13,384' TD = 13,$$3" KB ELEV = MAX ANGLE "48,45 (~ 11,067' UNOCAL CORP, ,,,----% WT GRADE Wel]~'u~.,, ~, ~ ~.ctual Recom pletion(3/25J98) ii It ....... II i. i .......i AND TI"Bi~, ~F. TAIL CONN Il) 'roi, Irl'M. CMT NO. Depth t l 1,842' 2 11,843' 1. t,848' 4 11,891' Wel0 Surf 60 t' Seal Lo~k 12._s 1 ~ 9u~, 5960' Butt 8, 681 I 0,680' I 2,41 ~ BuU 8,68t 8~03' 10.680' Bu~ ~,t~ 6296' 8~03' Bu~ ~,83~ 4009' 6296' g~ 8.755 ~4' ~009' B~ 8.681 ~, ~4' DuE 6, l ~4 ~. 11,348' ~I72' 6174' E~, ~ Mod 2.992" 0' 6508' ST-L 2.~2" 6~08' 1 !.834' tO.,. I~ern 3-liT' cra/ 2.406 ~ K42 ~chor Tub~ 5e~ ~bly 3.25 B~e M~el 2.9~" B~I Seat Sub 2350 1300s"x Bad Casing from 12,780 to 13,154'. Squeezed with 300sx cement on 4/3/78 £I$I-I Baker Model DB Packer with seal bore extension Cmt Retainer lunked Pkr Cmt Retainer 3/23/95 (~13,384' 6/t8/74 ~13,462' 3/30/78 ~1 t,482' 4/2/78 (~1'.L482' ..... :--:_~--::.; ...JZZL... ' PERFORATION DATA L~ Zone Top Btm /Milt SPF Perf Date '--~:q .......... ~'2;12o' q244s' G-Z t2,1~' 12,210' G.s 12,S2Q' t2,610' G-S lZ,S8~' 12,TIS' H~i 12,646' 12,ge0' M' 16 ~6187 HE-3 12,904' 12,98g' 81' GI1~4 H~2 13,00~' 13,088' H~3 t3,108' 13, t42' Opan fl Inje~tleq Open fl InjeetJe Open fl Open fl Open fl InJectln[~ Open f/Injection Open fl InJ~lon omt 8q='d cmt $qz'd Cmt 9q~'d O- 16Proposed Recompletion,rtf REVISED: 11/5/'97 OPERATOR: MENTS: COMMENTS'. COMMENTS: ~OMMENTS: COMMENTS: STAT. E OF ALASYd~. ALASKA OIL AND GAS CONSERVATION COMMISSION Mecha~ilc~ Inlegdb] Tes[ DATE: ..... 1 I._ i t 1 ! l..... ~ I 1 [ f TBG: [NJ. FL[III) CODES FRESH WATER INJ. = GAS INJ. ~T WA~R ~J. . .'7- ,. TEST TYPE: M --ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R= INTERNAL RAD. TRACER SURVEY A = 'TEMPERA'lURE ,ANOM~Y TEST ANNULAR FLUID: P.P.G. Gre, d, WF~I l: TEST: DIESEL ! 0.00 Inlllal GLYCOL [ 0.01~ 4-Year o~ _ o. oo Jan. 6, 2000 6'48PM UNOCAL CORP. UNOCAL NO,UbU~ Date i 2it-. ~.lee8 M~A~LTH~JR RrVER IBU .I III IIIII F, /4. WFL Interpretation Summary A TDT-WFL Survey was run on 28-Jan-1998 to check the Mechanical Integrity of the tubulars under injecting conditions. The tool was run in the up,flow configuration with the annulus open and returning approximately 1000 bpd to the surface, The up-flow survey was then repeated with the annulus closed, The toot was then changed to the down-flow configuration and a down-flow survey Was completed, This report presents the most likely interpretation which could' be derived from the , measured data. Because of the complicated nature of, the tubular configuration in this well other possible flow paths may exist which could lead to the observed results. Summary of Findings: The Sliding Sleeve at 12042 is leaking. The Packer at 12073 is not leaking, The Tubing is leaking between 1500 and 3000 feet. The 7" casing has a leak between 6300 and 6500 feet. WFL Discussion: With the tubing x 7" annulus open during Injection the well was returning ~ I000 bpd to the surface. This flow originates from a leak in the sliding sleeve at 12042 feet. No flow was seen coming up past the packer at 12073 feet. With the tubing x 7" annulus closed up-flow continues at a reduced rate. This flow travels up the tubing x 7" annulus until between 6300 and 6500 ft where it exits the 7' casing and flows down the 7" x 9 5/8" annulus. Down-flow in the tubing x 7' casing annulus is seen starting between 1500 and 3000 feet. Thie flow continues down and appears to exit the 7" 'casing in the same Interval the up flow mentioned above (-6400 fi). This combined flow then travels down the 7" x 9 5/8" annulus to the reservoir at or below 12100 feet. Attached is a plot and tabular listings of the WFL Interpretation and field recordings. d~trl , 6, 2000 6'48PM UNOCAL CORP, ~/ (""-C_.,.- -" IIII III ONOOAL, TBU 0-16, TRADINOt BAY UNIT, WFL, 2'.9-Jab-. , (9801 ~O,UO~d o o o o 60 ~Eel;) 180 J~n . 6, 2000 6:49PM UNOCAL CORP, No,0~83 ZU Q-16 Temp w Depth Trap 20 ~0 40 50 50 70 80 90 100 110 120 180 1,000' -- 2,000' 3,,000' - 4,000' 6,000' -- 7,000' 6,000' -- ~,000' -- 10,000' -- 11,000' -- 12,000' -- ,~ ~i.l! ~, ~a~ Cons., Commission,. ADohorao~ Unocal Corporation 909 West 9~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 · Telephone (907) 263-7830 UNOCALe ..Y ., ~/// .- ../ / / ,//~l'om Maunder - - ,~r~"/~O, fe..~ ~'*','~/~ ~/~z~~ ~~~Alaska Oil ~d Gas Conse~ation Commission ~~ ~ /~~r~~~ ~ ~~ 3001 Porcupine Drive ~h~~ -- /--';'-- "/ / / ~. ~ Z~ J/ ~chorage,~99501 t,~~ ~e: ~esults of WFL s ~rom 1998 Grayfing worKover rrogram We ran a series of Water Flow Logs in 1998 to identify holes in the casing of a series of wells which had experienced tubing/casing communication. Our goal was to prove no holes in the casing and request a variance, which would have saved us over $8MM in repairs. Unfortunately, all the WFL's suggested holes in the casing. Even though only one of the temperature surveys showed a hole in the casing (which didn't correlate with a hole suggested by the WFL), we were so confident that the WFL's were correct we decided to bit the bullet and work the wells over and repair the casing holes. When we went to do the work there was good news and bad news. The good news was there was only one hole in any of the casings (the one the temp survey clearly showed - G-36DPN) and we were able to save over $3MM in repair costs. The bad news was we still spent over $4MM in workover costs which may have been unnecessary if we were able to obtain variances on them. I have attached three examples: G-36DPN G-22 G-16 WFL showed multiple leaks between 3000 and 5000 MD. Temp survey showed leak between 10,200 and 10,300 MD. Pressure testing confirmed leak identified by Temp survey and proved leak identified by WFL to be nonexistent. WFL showed multiple leaks between 4750 and 6000 MD. Temp survey showed possible leak between 8,900 and 9,400 MD. Pressure testing proved no leaks exist. WFL showed leak between 6300 and 6500 fi. Temp survey had minor temp variations over the length of the log but was interpreted as noise. Pressure testing proved no leaks exist. IfI Can be of further assistance please don't hesitate to call me at 263-7830 or Steve Tyler at 263-7649. Sincerely, Reasons for no WFL's on Baker.doc Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management JUN-OS-B8 FEI 14:U6 r. ul/u~ UNO~AL A~K'I' GA~ PAX NU. BU-fZ~2fSf4 Unocal Corporation Agricultural Products 909 West 9m Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCALe June 5, I998 Wendy Mahan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Grayling G-16: Minor Leak Causes no risk and is within AOGCC Guidelines. Dear wendy: This letter is to inform you that we have finished our testing the G-16 injection well and it is within the AOGCC ~ guidelines. The well passed a now MIT on 6/5/98 and tho wellhead check om goot We plan to continue injection into this well and hold backpressure on the annulus to minimize the leak. As with all of our injection wells we will closely monitor the pressure on the annulus and bleed offthe pressure as necessary. The current plan is to hold 2000 psi on the annulus and monitor for one week. If the pressure holds we will lower the pressure to 1500 psi and monitor for one week. We will continue this operation until we determine the minimum pressure which elhnirmtes the minor le~ak. If the pressure increases while attempting to hold thc pressure at 2000 psi, we will routinely bleed off the pressure when it reaches 2300 psi back to 2000 psi. Please sign and send a copy of this letter to my fax at 263.7874 otherwise call me at 263-7830. RECEIVED Senior Reservoir Engineer j "~ ?~,,~ G 5 t~ Cook Inlet Watcrflood Management Alaaka 0il & Gas Cons. commissio~ Anchorage Please return a signed and dated copy of this letter to document your agreement with this operation for our records. Wendy~lVl~han Date AOGCC Aogcc G-16 Leak Resolution.doc 06/05/98 JUN-02.98 TUE 10:05 UNO~,RSSET G6S GRP F~X NO. 9072637874 P, 02/05 JUN 02 ~98 Unocal Corporation Agricultural Products 909 West 9~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCALe June 2, 1998 Wendy Mahan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Increasing Casing Pressure on Grayling G-16 6%- loel Waterflood Injection Well Dear Wendy: This letter is to inform you of a gradual increase in the tubing/casing annulus pressure on the Grayling G- 16 well. This well was worked over in March ~md began injection on 3/27/98 after passing a conventional MIT. Between 3/27 and 4/19 the casing pressure held steady n~u' Il00 psi, then on 4/19 Lou Grimaldi requested to witness another MIT while he was on the platform and it passed. Since 4/19 the well has experienced a steadily increase in casing pressure of 15 psi/day. The casing pressure was bled down on 5/1 to 500 psi and is currently at ll00 psi due to this steady leak. We would like permission to continue injection while we conduct a wellhead inspection and a new MIT. I have attached copies of the MIT's and recent pressure history for your information. Please sign and send a copy of this letter to my fax at 263-7874 otherwise call me at 263-7830. Senior Reservoir Engineer Cook Inlet Waterfloed Management Please return a signed and dated copy of this Ictter to document notification for our records. AOGCC ' AOgcc G-I6 Leak.doc 06/02/98 STATE C~ \LASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: UNOCAL FIELD I UNIT I PAD: McArthur riverFl'radin~l Bay/Grayling DATE: 4/19/98 8,746 1500 m/~ 2,200 2,200 2,200 2,200 G-22 ~afe P KCL 9,897 9 5/8, 47#, N-80 ~ J 2187 1,050 2,300 2,,,300 2,300 g30 P COMMENTSPr'~tes/pressures observed for thirty minutes prior to pressureing up annulus. 2,25o ,, ,, I , , 2,250 COMMENTSPFetest Pressures observed for thirty minutes prior to pressureing up annulus. ~05O I ~0~0 ~4:, I * ~, 47#, N-,0 ~r~[ ~,~ [ ~5o ~ ................ 2~5o '~ COMMENTSPI~otest pressures observed for thbty minutes ptfor to pressureing up annulus. ....... ~50omin .......... .'.'..'.'i..'..'~'! ! ~-q.. I ,o, .... ! !.'~! I COMMENTS: I I !' ~ ......... I [=°°o'""[-- !,., I'"'! .... ! "l~l COMMENTS: , , . ,,,, . ,,,,. z TBG. INJ. FLUID CODES TEST TYPE: F = FRESH WATER INJ. M -- ANNULUS MONITORING G = GAS INJ. P = STD ANNULUS PRESSURE TEST S = SALT WATER INJ. R = INTERNAL RAD. TRACER SURVEY N = NOT INJECTING A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P.G. DIESEL GLYCOL SALT WATER 9.3 DRIMJNG MUD OTHER Grad. WELL TEST: 0.00 Initial X 0.00 4 -Year 0.48 Workover 0.00 Other 0.00 Di~: mg- we~ Fae ¢- Opemt~ c - Trip Rl~ File PERATOR REP SIGNATURE: Johnny T. ~ , AOGCC REP SIGNATURE: Louis R. Grimal~ jugjdsfe.)ds (Rev 9117/o-36) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ o, ....c~.~ ;~oc,~0 ~u~ / u~-r / p^D: ,~//,~///,O'& .... uA'r;.- ~ - ~ 7- ~,~ii~il~.'~~;~ =~'* ~'~ ";:~;~t~; ~~;~.~~~. ~'~ .... ...... ;~;' ::~;~'"~:~<.a~.., *~ ~;~=;. ~, ~:~;~*"~-i.=.:.~,~ ..... .~ ,=;~'~."'i'~~-~a~." -"~ ~ ~ ...... ' ~ - ~ '"'~ '~"" .,~;.~,..~.~' ........... ~;~. ....... '~'. "' ................. ~E,:i~;~,~"~;~..,a. ;;~. ?~,.~c .-';'i~?~ ~,~i~*~ ' .;'.. :~'~. ' : ' ' ~* ~"" ,~'i :, ~' '* .... :'. '~. I. I -! ' ] ~ ................. ~ 1_",{ ";~'_~{' "' 1'''~ :-'{ ........ "' ........ '"'~ -1.~" _.1'~ I F"- ::I~~ I . , .... :"~':-[ "I ' ' :-~':I- I .... !' OO~T~ COM~B: T~G. I1~. FLUID CODES F = FRESH W~TER INJ. G = GAS lieU. SALT WAI'~R lieU. bi = NO1' INJECTING TEST TYPE= M = ANNULUS MONITO:RtNG P =STO ~ PRESSURE TEST R= INIERNN. RAD, TRACER SURVEY A = TEMPERA~ N,K)MALY TEST D = DIFFERENTIAL ~TURE ~T .' "-/' · t ANNULAR ~'~.UID: P.F).G. Grad. c4-vuou~- I s~.~W^tEr ~,-'X' _1 -~ MUD- ~ { ~.~ ~)00 7OOO 6OOO 5~X~3 3OO 2OO Grayling Injection Information 160 16G 30 days of Morning Grayling Inj~:fion Data 6/2198 9:56 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 99' to MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, Alaska Service: X Trading Bay Unit 4. Location of well at surface 8. Well number 1879' FSL, 1381' FEL, Sect 29, T9N,R13W, SM (Conductor 49, Leg 2) TBUS G-16 At top of productive interval 9. Permit number/approval number 977' FSL,617' FWL, Sec 27, T9N, R13W, SM 68-109 At effective depth 10. APl number 364' FSL, 1403' FWL, Sec 27, T9N, R13W, SM 50-133-20162-00 At total depth 11. Field/PoOl 258' FSL, 1507' FWL, Sec 27, T9N, R13W, SM Mr.,Arthur River Field 12. Present well condition summary Total depth: measured 13,663' feet Plugs (measured) true vertical 10,129' feet Effective depth: measured 13,384' feet Junk (measured) Milled out Baker Model D packer at 13,384' true vertical 9,917' feet Casing Length Size Cemented Measured depth True vertical depth Structural 376' 26" Driven 376' 376' Conductor 601' 17-3/4" 750 sx 601' 601' Surface 5,960' 13-3/8" 2350 sx 5,960' 4,568' Intermediate 12,416' 9-5/8" 1000 sx 12,416' 9,249' Production 13,663' 7" 1300 sx 13,663' 10,129' Liner Perforation depth: measured (See Attachment) true vertical 0RI61NAL Tubing (size, grade, and measured depth) 3-1/2" L-80 EUE Mod 9.3 Ib/ft at 6508' 3-1,2" L-80 ST-L 9.3 Iblft at 11,834'RECEIVED Packers and SSSV (type and measured depth) Baker Model 84SAB40x32 Permanent packer set at 11,843' i,,,? 2:i998 13. Stimulation or cement squeeze summary ~.-., ~' ~ ~ Intervals treated (measured) Alaska 0il & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 6300 BPD 2850 psi 3150 psi Prior to well operation (1/28/98) Subsequent to operation (3/28/98) 6000 BPD 1000 psi (maintained) 3000 psi 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: Service: Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: /,~~ f,,, ~ ~ ~,,~_,~ Title: Drilling Manager Date: ~ -~/~ i/~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Grayling G-16 Summary of Operations Well work was required on G- 16 water injector to repair tubing to casing communication and to further investigate if there was a hole in the tubing above the uppermost packer. The existing completion was recovered which indicated leaks in the production tubing above the uppermost packer and parted tubing above the lower packer. Following a clean out run to well ETD a RTTS was utilized to test the casing integrity above the planned setting depth of the single injection packer. Pressure tests were made at 11,400' and 11,850' with the following results: Depth Initial Pressure Final Pressure Time 11,400' 3500 psi 3500 psi 15 min 11,850' 3740 psi 3688 psi 30 min Following this the well was re-completed as a 3-1/2" single injector with the injection packer set at 11,843'. Subsequently a MIT was conducted (attached) which indicated mechanical integrity. The well was put back on injection on 327 March 1998. /'.?R 02 1998 Alaska Oil & Gas Cons. Commission Anchorage Trading Bay 'Unit Well # G-16 Actual Recompletion(3/25/98) RKB to TBG Head -- 41.35' G-1 G-2 G-3 12,416'L 12,780' 13,154' G-4 -= G-5 --- G-6 HB-1 HB-2 HB-3 HB-4 ETD = 13,384' TD = 13,663" KB ELEV = 99' MAX ANGLE = 48.45 ~ 11,067' G- 16Proposed Recompletion.rtf CASING ANT) TUBING DETAIl, SIZE WT GRADE CONN ID TOP BTM. CMT 17-3/4" .312 wall Weld Surf. 601' 13-3/8" 61 K-55 Seal Lock 12.515 Surf. 5960' 9-5/8" 47 P-110 Butt 8.681 10,680' 12,416 9-5/8" 47 N-80 Butt 8.681 8503' 10,680' 9-5/8" 43.5 N-80 Butt 8.755 6296' 8503' 9-5/8" 40 N-80 Butt 8.835 4009' 6296' 9-5/8" 43.5 N-80 Butt 8.755 54' 4009' 9-5/8" 47 N-80 Butt 8.681 Surf. 54' 7" 29 P-110 Butt 6.184 11,345' 13,663' 7" 29 N-80 Butt 6.184 Surf. 11,345' 7" DV Collar 6172' 6174' Tubing: 3-1/2" 9.3 L-80 EUE. AB Mod 2.992" 0' 6508' 3-1/2" 9.3 L-80 ST-L 2.992" 6508' 11,834' 2350 sx 1000 sx 1300 sx JEWELRY DE'I'AIL NO. Depth I'D Item 41.35" 1 11,842' 2.406 2 11,843' 3.25 3 11,848' 3.75 4 11,891' 2.813" 5 11,925' 2.992" 3-1/2" CIW DCB Tubing Hanger 3-1/2" Butt x 3-1/2" El3E Baker K-22 Anchor Tubing Seal Assembly Baker Model "84SAB40x32" Penn Pkr. 3.25" ID Baker Mill out Extension Baker "X": nipple profile Ball Seat Sub Bad Casing from 12,780 to 13,154'. Squeezed with. 300sx cement on 4/3/78 FISH Baker Model DB Packer with seal bore extension Cmt Retainer Junked Pkr Cmt Retainer 3/23/98 ~13,384' 6/18/74 ~ 13,462' 3/30/78 ~ 13,482' 4/2/78 ~13,482' PERF~ORATION DATA Accum LaSt Zone Top Btm Amt SPF Perf Date G-1 12,120' 12,145' 25' 12 4125/87 G-2 12,164' 12,210' 46' 12 4/25/87 G-3 12,275' 12,315' 40' 12 4125/87 G-4 12,335' 12,450' '1 t5' t 2 4/25187 G-5 12,520' 12,610' 90' 12 4125187 G-6 12,685' 12,725' 40' 12 4/25187 HB-I t2,845' t2,890' 45' 16 4125187 HB-2 12,904' t2,985' 81' 6114/74 HB-2 t3,005' t3,088' 83' 6114/74 HB-3 13,108' 13,142' 34' 6/14/74 HB-4 13,t72' 13,270' 98' 20 4125187 Present Condition Open fl Injection Open f/Injection Open f/Injection Open f/Injection Open fl Injection Open fl Injection Open fl Injection Cmt Sqz'd Cmt Sqz'd Cmt Sqz'd Open fl Injection RECEIVED Alaska 0il & Gas Cons. Commi,,~lo~ REVISED: 11/5/97 1I¢,R-27-98 FRI 13:52 UNOCAL ASSET GAS GRP FAX NOi 90726,2,7~74 F, U1/U1 ~o8- ~ oel Unocal Corporation 909 West 9'~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL ) March 27, 1998 Wendy Mehan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status of Unocal's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update of the work conducted since our January 23, 1998 letter which Blair signed granting time extensions for various wells. Testing or work ~vas completed on thc following wells and the results of this work is listed: Anna 29-42: Well head inspection completed (no teaks), Variance granted on 313/98. Baker 4: MIT passed on 2/15/98 by Lou Grimaldi Bruce 31-42: Coil Tubing operation completed to repair leaking cement plug. Pressure test completed. GP 33-14RD: SI MIT successfully completed on 2/11/98. GP 22-13RD2: Variance granted on 3/17/98, MIT completed on 12/15/97. - Grayling 16: Workover completed on 3/26/98. MIT Passed. Monopod A-SRD2: MIT passed on 1/28/98 by Lou Gfimaidi Testing or work was attempted on thc following shutdn wells and a time extensign tmtil June 30, 1998 is requested to comolete further work and testing. Anna 19-42: Scale cleanout of tubing completed, further testing scheduled to prove casing integrity. Anna 2%42: Scale cleanout of tubing completed, further teeing scheduled to prove casing integrity. Anna 4642: Temp Survey ran on 2/17/98, survey should prove no flow and allow SI status. Baker 9: MIT attempted on 2/15/98, further wireline testing scheduled to prove casing integrity. Monopod A-12RD2: SI MIT attempted, Temp Surwy scheduled to prove no flow. Monopod A-29 : SI MIT scheduled to prove no flow/casing integrity King 4RD : WFL indicates possible easing leak, well shutin, further testing and workover scheduled. King 15RD: WFL indicates possible casing leak, well shutin, further testing scheduled. King 22RD: WFL indicates possible casing leak, well shutin, further testing scheduled. Grayling 5 : Workover/Redrill scheduled in current drilling schedule. Grayling 22 : Workover/Redrill scheduled in current drilling schedule. Grayling 28 : Workover/Redrill scheduled in current drilling schedule. Grayling 36DPN : Workover/Redrill scheduled in current drilling schedule. Grayling 40 : Workover/Redrill scheduled in current drilling schedule. Unocal respectfully requests a time-extension until June 30, 1998 to complete the work on the above listed Anna, Baker and Monopod wells. The Grayling and King work will be executed per our current drilling schcdul_e._~lF,,ilSC call mc if you have any questions or clarification on these issues. R E C E i V E D ~ MAr~ 27 'i998 Cook Inlet Waterltood Mana~ dii & Gas ConS. commission Anchorage Please acknowledge the approval of the time extension and)'our receipt of this letter by faxing back a signed copy of this letter to Christopher Ruff at 263-7874 (fax). endy~d/ghan Da~ ! - AOGCC , STAT.E OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanlc~.l Integrity Test OPERATO,R: Union O!l_.CompanY (UNOCAL) FIELD/UNIT/PAD: ~'///~y/'//~/'~ DATE: '~--- :~:;:~:~;':{i:~i~;-'.'-=~'-';G':~-"~~ ~.,:.;.:.. ;,.,1 ":"':"':~':'= .......... "'~ ':~"-'"-':'~:'-~'.:.';.::~-:-'-:'~:~:~',:~-'~ i,.-.~-,.'-'"~'~:::':""~.,~,- ' ":"" '"'"' !:m~:'..:~,'.'..,,~, '""~ : ':~' "~ :--,',"-'~'~"-"--'""~-:~""':'"~-' "":'-'"'-'-":" ~"~ .:'~- .... :~"~."'" ~~' :~-"':~'~'~': "'; ... ...... ,,.~.-....~...,~..., ,-.,:.:.,,,.::,, ....~.. ........................................... ...~.... ,~,:, .................. ,~, .:=.~.:::,,~.:...:,..~... ;~,,~,.,.~.,~::..' !~.;-~.S..~!i ,;~.. .,: ....~.,::~:~.=;~=~.,~ :,~..: .~=~.,~..~:;'.'-=.~i: ~bUMENTS: ............ ' ............................. cOMMENTS: "'" ' '1"' ....... co~.~dq.rs: ..... I 1 ..... COMMENTS: ........................... , ..... TBG. INJ. FLUID CODES FRESH WATER IN Jo GAS INJ. SALT WATER IN J. = NOT INJECTING. TEST TYPE: M = ANNULUS MONITORING P = ST[3 ANNULUS PRESSURE TEST R = iNTERNAL PAD. TRACER SURVEY A = 'fEMPERA'I'URE ANOMALY TEST D = DIFFERENTIAL TEMPERA3'URE TEST ANNULAR FLUID: P.P.G. Grad. WELLTEST: DIESEL~ . _ I 0.00 lnillal GLYCOL ~ 0.0O 4 - Year SALTWATER-- ' ~ ~ -i 0.00 Workover X~ DRILLING MUD ~'~ 0.00 Other--' OTHER ~ 0.00 Unocal Corporation Agricultural Products 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL Feb 13, 1998 Blair Wondzell State of Alaska R E C E I ~/E D Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive [:~ 2 0 1998 Anchorage, AK 99501 Alaska 0il & Gas Cons. Commission Anchorage Re: Grayling G-16 10-403 Application for Approval to Repair Well and Extend Variance Dear Blair: As promised in previous correspondences, we are submitting a 10-403 Application for Approval of the G-16 workover project and variance which will allow us to inject imo the well without repairing the casing leak. Due to the limited life of the field, the plan is to put a new completion in the well which will isolate the injection interval from the annulus above the packer. The well will be tested by raising the injection pressure to normal operating conditions while monitoring the casing pressure on the well. A large differential pressure between the robing and casing will demonstrate tubing/packer integrity. Following the workover the daily pressures will be reported to you on a monthly basis. If casing pressure is recognized during the daily monitoring, the well will be immediately shut-in and a plan will be developed to deal with the problem. Please approve the application and return an approved copy of the 10-403 for our records. If you have any questions please call me at 263-7830. Senior Reservoir Engineer Cook Inlet Waterflood Management I' ' STATE OF ALASKA ,"-" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: 99' to MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface 8. Well number 1879' FSL, 1381' FEL, Sect 29, T9N,R13W,SM (Conductor 49, Leg 2) TBUS G-16 At top of productive interval 9. Permit number 977' FSL, 617 FWL, Sec 27, T9N, R13W, SM 68-109 At effective depth 10. APl number 364' FSL, 1403' FWL, Sec 27, T9N, R13W, SM 50-133-20162-00 At total depth 11. Field/Pool 258' FSL, 1507 FWL, Sec 27, T9N, R13W, SM McArthur River Field ,.. 12. Present well condition summary K L L ~ IV Total depth: measured 13,663' feet Plugs (measured) true vertical 10,129' feet FEB 2 0 3998 Effective depth: measured 13,482' feet Junk (measured) true vertical 10,012' feet Alaska 0il & Gas Cons. Commissio~ Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural 376' 26" Driven 376' 376' Conductor 601' 17-3~4" 750sx 601' 601' Surface 5,960' 13-3~8" 2350sx 5,960' 4,568' Intermediate 12,416' 9-5~8" 1000sx 12,416' 9,249' Production 13,663' 7" 1300sx 13,663' 10,129' Liner Perforation depth: measured (See attachment) true vertical Tubing (size, grade, and measured depth) 3-112" x 2-718" N-80 SL conn. at 12,821' Packers and SSSV (type and measured depth)Baker Model DB @12,750' (DIL)and Baker Model DB @ 12,048'0RIGINAL 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 3/15/1998 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: a,~~--~ ~1 c~t... Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval N~._~'C,~ Plug integrity BOP Test u'~ Location clearance Mechanical Integrity Test ~'~ Subsequent form required 10- ~0l-I. ;j[r'~[ t ~" ' r~~ Original Signe[I By David W. Johnston Approved by order of the Commissioner Commissioner Date ~. ~-~-~.~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Grayling G-16 Summary of Work Program Grayling G- 16 Injector workover was originally proposed to repair tubing to casing communication and restore access to existing perforations. An AOGCC Form 403 describing the work program was submitted for approval the second week in January 1998. In light of the new information regarding the anticipated leak in the production casing, the attached revised program describes the well work which would now be carried out. In short the workover would entail the following steps: · Remove all the existing tubing in the well and uppermost packer. · Conduct a leak investigation with a RTTS packer and USIT log to determine the nature of the leak at 6500' to 6300'. · Restore the well to a serviceable condition. · Carry out a modified MIT test to demonstrate the tubing/packer integrity. RECE VED /~laska 0ii & Oas Cons. Commission ~.nch0rage Grayling G-16 Perforation Record Measured Depth Tree Vertical Depth 12,120-12,145' 9,057'-9,076' 12,164'-12,210' 9,090'-9,124' 12,275'-12,315' 9,173'-9,202' 12,335'-12,450' 9,217'-9,300' 12,520'-12,610' 9,350'-9,414' .12,685'-12,725' 9,465'-9,491' 12,845'-12,890' 12,904'-12,985' 9,571'-9,601' 9,609'-9,663' 13,005'-13,088' 9,676'-9,730' 13,108'-13,142' 9,742'-9,767' 13,172'-13,270' 9,783 '-9,846' Grayling G-16 BHP and Proposed Workover Fluid Static BHP G-Zone: Hemlock: 3300psi at 9057'TVD 4000psi at 9570'TVD Proposed Workover Fluid Maximum Pressure Gradient: Workover Fluid: .42psi/ft (Hemlock Bench 1) .44psi/ft (Formation Inlet Water +3%KCL) RKB to TBG Head -- 41.5' Tree connection: 12,780, G-1 G-2 Suspected breach in tbg I integrity ~ 12,220' WLM. I LIB ran on 8/4/97 G-3 G-4 G-5 G-6 11 Bad csg f/ ~ 12.780' - 13,1541 Sqz'd w/300 sxI of chi on 4/3/78] 13,154' HB-1 HB-2 HB-3 HB-4 ETD = 13,482' TD = 13,663" KB ELEV = 99' MAX ANGLE = 48.45 {~ 11,067' G-16.rtf NOTE: 12' Diff. between DP & DIL 12.24' Diff. between tbg & DP 24.24' Diff. between DIL & tbg Trading Bay 'Unit Well # G-16 Re-Completed 5/8/87 CASING AND TUBING DETAIl., SIZE WT GRADE CON.N ID TOP BTM, CMT 17 -3/4" .312 wall Weld Surf. 601' 13-3/8" 61 K-55 Seal Lock 12.515 Surf. 5960' 9-5/8" 47 P-110 Butt 8.681 10,680' 12,416 9-5/8" 47 N-80 Butt 8.681 8503' 10,680' 9-5/8" 43.5 N-80 Butt 8.755 6296' 8503' 9-5/8" 40 N-80 Butt 8.835 4009' 6296' 9-5/8" 43.5 N-80 Butt 8.755 54' 4009' 9-5/8" 47 N-80 Butt 8.681 Surf. 54' 7" 29 P-110 Butt 6.184 11,345' 13,663' 7" 29 N-80 Butt 6.184 Surf. 11,345' 7" DV Collar 6172' 6174' Tubing: 3-1/2" 9.3 N-80 S.L. 2.992 0' 12,072' 2350 sx 1000 sx 1300 sx · '}_,'l/fl,, t~ A ~..T-fl*q q f q* AA1 1'9 "}rio 1"1 'Tq'l~' Integrity Note: While injecting ~ 4 BPM, 2050 psi down the 9-5/8" X 13-3/8" annulus,a Temp Log ran on 4/23/87 revealed injection to 6060'. Cmt sqz'd, down the annulus w/800 sx of class "G". Noted PBU on annnhtq on ~;/1/R7 hied nfl built haek-nn tn R00 n.~i F.~tahli~hed nn injection rate ~) 9.(i0O n~i on JEWELRY DE'I.'AH., NO. Depth ID Item 41.5 1 12,042' 2.75 2 12,072' 2.406 3 12,073 3.25 4 12,076' 3.25 5 12,086' 2.441 6 12,087' 2.760 7 12,088' 2.992 8 12,209' 2.441 9 12,237' 2.441 10 12,773' 2.406 11 12,774' 3.25 12 12,778' 3.25 13 12,816' 2.313 14 12,845' btm 12,846' 3-1/2" CIW Stainless Tubing Hanger Otis "XA" Sldg Slve Locator Seal Assy. w/8.6' of seals. Baker Model "DB" Perm Pkr. 80-32 Seal Bore Ext. Crossover, Seal Bore Ext. Box X 2-7/8" Seal Lock Pin Crossover, 2-7/8" Seal Lock Box X 3-1/2" Seal Lock Pin 4jts of 3-1/2", 9.2#, N-80, [PC, Seal Lock Tbg. Crossover, 3-1/2" Seal Lock Box X 2-7/8" Seal Lock Pin Teledyne-Mefla Flow Mandrel Locator Seal Assy w/8.69' of seals. Baker Model "DB" Pkr. 12,750' DIL 80-32 Seal Bore Ext. Otis "X" Profile Nipple WLEG FISH Cmt Retainer 6/18/74 ~ 13,462' Junked Pkr 3/30/78 ~ 13,482 Cmt Retainer 4/2/78 ~ 13,482 STIMULATIONS Acidize wi 4000 gals of 12-3 mud acid & 800 gals of E-95 solvent. 7/20/74 HB-4 Fracture Stimulated w/13,500# of sand into peffs. 7/20/74 HB-4 Acidize w/4000 gals of 15% HCL & 10,000 gals of 12-3 mud acid. 4/6/78 HB-4 Acidize w/16000 gals of 7.5% HCL 4/29/87 "G" Zone Acidize wi 35,700 gals of 12-3 mud acid. 5/3/87 "G" Zone SLICKLINE WORK Tagged XO w/2.7W GR 8/3/97 @ 12,079' WLM (12,086' MD) Tagged obstruction w/2.23" GR 8/3/97 ~ ]2,220' WLM 2.25' LIB showed deep gouges on side & smaller in middle 8/3/97 @ 12,220' WLM PERFORATION DATA Accum Last Zone Top Btm Amt SPF Perf Date Present Condition G-1 12,120' 12,145' 25' 12 4/25187 Open f/Injection G-2 t2,164' 12,210' 46' 12 4125/87 Open fl Injection G-3 12,275' t2,315' 40' 12 4/25/87 Open fl Injection G-4 12,335' 12,450' 115' 12 4125/87 Open fl Injection G-5 12,520' 12,610' 90' 12 4125/87 Open fl Injection G-6 12,685' 12,725' 40' 12 4125/87 Open fl Injection HB-I t2,845' 12,890' 45' t6 4125187 Open fl Injection HB-2 12,904' 12,985' 81' 6/14/74 Cmt Sqz'd HB-2 t3,005' 13,088' 83' 6/14/74 Cmt Sqz'd HB-3 13,108' t3,t42' 34' 6114/74 Cmt Sqz'd HB-4 13,172' 13,270' 98' 20 4125/87 Open fl Injection REVISED: 8/5/97 DRAWN BY: SLT RKB to TBG Head = 41.5' Tree connection: 5 G-1 i G-2 G-3 12,780, 7 8 13,154' ETD = 13,482' TD = 13,663" KB ELEV -- 99' MAX ANGLE = 48.45 ~ 11,067' G-4 G-5 G-6 HB-1 HB-2 HB-3 HB-4 NOTE: 12' Diff. between DP & DIL[ 12.24' Diff. between tbg & DP I 24.24' Diff. between DIL & tbg I Trading Bay 'Unit Well # G-16 Proposed Recompletion SIZE WT CASING AND 'I'U'BING .DETAIl., GRADE CONN ID TOP BTM, CMT 17-3/4" .312 wall 13-3/8" 61 9-5/8" 47 9-5/8" 47 9-5/8" 43.5 9-5/8" 40 9-5/8" 43.5 9-5/8" 47 7" 29 7" 29 7" DV Collar Tubing: 3-1/2" 9.3 Weld Surf. 601' K-55 Seal Lock 12.515 Surf. 5960' P-110 Butt 8.681 10,680' 12,416 N-80 Butt 8.681 8503' 10,680' N-80 Butt 8.755 6296' 8503' N-80 Butt 8.835 4009' 6296' N-80 Butt 8.755 54' 4009' N-80 Butt 8.681 Surf. 54' P-110 Butt 6.184 11,345' 13,663' N-80 Butt 6.184 Surf. 11,345' 6172' 6174' L-80 EUE. Mod 2.992" 0' 12,000' 2350 sx 1000 sx 1300 sx NO. Depth 1'.~, 41.5 1 11,999" 2.406 2 12,000' 3.25 3 12,000' 3.25 4 12,045' 5 12,075' 2.441 6 12,774' 3.25 7 12,778' 3.25 8 12,816' 2.313 9 12,845' btm 12,846' JEWELRY DETAIL Item 3-1/2" CIW DCBStainless Tubing Hanger Baker Anchor Tubing Seal Assembly Baker Model "SAB" Penn Pkr. 4" ID Baker Mill out Extension Baker "X": nipple profile WLREG Baker Model "DB" Pkr. 12,750' DIL 80-32 Seal Bore Ext. Otis "X" Profile Nipple WLEG IBad Casing from 12,7,80'-.13,154'. Squeezed with 300sx cement on 4/3/78 FISH Cmt Retainer Junked Pkr Cmt Retainer 6/18/74 ~ 13,462' 3/30/78 ~13,482 4/2/78 @13,482 Zone G-1 G-2 G-3 G-4 G-5 G-6 HB-1 HB-2 HB-2 HB-3 HB4 Top 12,120' 12,164' 12,275' 12,335' 12,520' 12,686' 12,845' 12,904' 13,005' t3,108' 13,172' PERFORATION DATA Accum LaSt Btm 12 145' 12 210' 12 315' 12 450' 12 610' t2 725' 12 890' 12 985' t3 088' 13 142' 13 270' Amt SPF Perf Date 25' 12 4125187 46' 12 4125187 40' 12 4125187 t 15' t2 4125/87 90' 12 4125/87 40' 12 4125187 45' 16 4125/87 81' 6114/74 83' 6114/74 34' 6114/74 98' 20 4125/87 Present Condition Open fl Injection Open fl Injection Open fl Injection Open fl Injection Open f/Injection Open f/Injection Open f/Injection Cmt Sqz'd Cmt Sqz'd Cmt Sqz°d Open fl Injection G-16Proposed Recompletion.rtf REVISED: 11/5/97 Unocal Alaska Business Unit Grayling Platform Well Grayling G-16 Injector AFE # 130075 Prepared by: Neil Magee Date:Il/25/97 Revision #2 UNOCAL~ No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) 1 Rig up on well 24.0 24 1.0 2 Check for tubing pressure and set BPV. 2.0 26 1.1 3 N/U and test 13-5/8" 5K BOP's 8.0 34 1.4 4 P/U landing joint and screw into hangar top. 4.0 38 1.6 5 Pull tubing assembly loose from top packer at 12,060' and monitor well. 2.0 40 1.7 6 Displace well with FIW and monitor returns through gas buster. 4.0 44 1.8 7 POOH laying down tubing 16.0 60 2.5 8 P/U 3-1/2" DP and RIH with packer milling assy. 14.0 74 3.1 9 Mill over packer 22"+/- 2.0 76 3.2 10 POOH with packer milling assembly. 8.0 84 3.5 11 RIH with spear and engage packer at 12060' 8.0 92 3.8 12 Pull packer assembly and parted tubing(?) at 12,220' 10.0 102 4.3 13 RIH with overshot dressed to recover tubing stub. 8.0 110 4.6 14 POOH with tubing stub and and seal assy from lower packer at 12,762' 10.0 120 5.0 15 Rig up Schlumberger and run USIT log from 12,100: to surface 8.0 128 5.3 16 Make up 7" RTTS and RIH to 12,100'. Conduct leak investigation. 18.0 146 6.1 17 R/U slickline. Make dummy run to check for access through lower packe: 6.0 152 6.3 18 R/U Schlumberger and make gage ring mn. 4.0 156 6.5 19 Run permanent packer on wireline and set at 12,000'. 6.0 162 6.8 20 Run 4-1/2" completion tubing with seal assy. 14.0 176 7.3 21 Displace well to inhibited packer fluid. 4.0 180 7.5 22 Stab seals in and space out. Land tubing hanger and test. 2.0 182 7.6 23 Run BPV and N/D BOP's 6.0 188 7.8 24 N/U tree and test to 5000 psi 6.0 194 8.1 25 Conduct MIT to verify tubing/packer integrity. 8.0 202 8.4 Swr AFEG-16.xls Page 1 of 1 2/13/98 3" KILL L~NE WITH Two ~" 5,~ VALVES I ,'L,' d; KILL LINE FROM MUD PUP ~ CEMENT UNIT BELL NIPPLE ~ FLOWLINE =! , 15-5/8" 5000 PSI ANNULAR PIPE RAMS BLIND. RAMS PIPE RAMS I 13-5/8" 5M FLANGE DOUBLE GATE 5M 15-5/8" 5M FLANOE 4." CHOKE LiNE WITH ONE REMOTE ~ I ,ktANUAL 4." 5M VALVE {b', (I," CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE RISER 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M SPOOL 15--5/8" DOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (d,bd UNOCAL) -gRAWN: DAC APP'D: GSB SCALE: NONE DATE: 6/:24/91 MIXING PIT 40 13BLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM / 185 BI3LS VOLUME PIT TRIP TANK ~5 BBLS 185 Bi3LS SUCTION PIT 1125 BBLS 67 BBLS 240 BBLS ~ SHAKER SHAKER i , 'i [ ' ICENTRIFUGE RESERVE PIT 475 BBLS NOTE: THE SYSTEM WilL BE EQUIPPED WffH A DRILLING PIT LEVEL INDICATOR WITH AUDIO &: VISUAL WARNING DEVICES. EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 3) (2) SHAKERS 4) PIT LEVEL INDICATOR (VISUAL & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS 8) DESILTER CENTRIFUGE 10) MIXING PIT UNOCAL GRAYLING MUD PlY SCHEMATIC DRAWN BY: DAC APP'D: GSEI SCALE: NONE DATE: 11-30-89 TO ~A$ SUSTER /\ AUTOMATIC CHOKE TO DERRICK VENT I I TO WELL CLEAN TANK 4-1/16" 3-1/8" FROM CHOKE LINE AUTOMATIC CHOKE VALVES UPSTREAM OF CHOKES ARE 10,000 PSI GATE TYPE VALVES DOWNSTREAM OF CHOKES ARE 5,000 PSI GATE TYPE CHOKE MANIFOLD GRAYLING PLAI"F'OR M UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: OAC APP'D' GS8 SCALE: NONE DATE: ~ ~/2~/~ f"',, STATE OF ALASKA ALASKA AND GAS CONSERVATION L,,,)MMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request Abandon: Suspend: Operation shutdown Re-enter suspended well Alter casing: Repair well Plugging: Time extension X Stimulate: Change approved prograrr Pull tubing: Variance: Perforate: Other: UIC Waiver 2. Name of Operato 5. Type of well 6. Datum elevation (DF or KB UNOCAL Development X 99' ET to MSL feel 3. Address Exploratory 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 1879'N-1381'W f/SE cor., Sec. 29, T9N R13W SM G-16 At top of productive interv, 9.~P~F~nit npmJ~el~ 669' N - 1052' E f/SW cor., Sec. 27, T9N R13W SM~(K~-'- [(~ ~ 7-232 At effective deptl' 10. APl number ' 432' N - 1327' E f/SW cor., Sec. 27, T9N R13W SM 5o-733-20162-0c At total deptl' 11. Field/Poo 317' N - 1462' E f/SW cor., Sec. 27, TgN R13W SM McAurthur River / Hemlock & G-zone 12. Present well condition summar Total depth: measurec 13,663' feel Plugs (measured', true vertica 10,129' feel Effective depth: measurec 13,482' feel Junk (measured~ true vertica 10,012' feel Casing Length Size Cemente¢ Measured deptl' True vertical deptl' Structural 376' 26" Driven 376' 376' Conductor 601' 17 3/4" 1850 sx 601' 601' Surface 5,960' 13 3/8" 2359 sx 5,960' 4,568' Intermediate 12,416' 9 5/8" 1000 sx 12,416' 9,249' Production 13,663' 7" 1300 sx 13,663' 10,129' Liner Perforation depth measurec See Attchmenl true vertica Tubing (size, grade, and measured depti' 3-1/2", 9.2#, N-80 @ 12,805' Packers and SSSV (type and measured dept~ Baker Perm pkrs @ 12,048' and 12,750' 13. Attachement.~ Description summary of proposal Detailed operations prograrr BOP sketch: 14. Estimated date for commencing operatic 15. Status of well classification as 16. If proposal well verbally approvee Oil: Gas: Suspended: Name of approve Date approve( Service: Water Injection 17. I h~reby ce~./~p.~?.,/~ue and correct to the best of my knowled.( ~ ///~ ,~~'~ FOR COMMISSION USE ONLY z Condition's of approval: Notify"Commission so representative may witne I Approval No,, Plug integrit~ BOP Test Location clearanc~ I Mechanical Integrity Tes Subsequent form required 10 -, l~e~ .~t- Approved by order of the CommissionE C~.~,~ Commissioner Date ~':~/~___~/I~ ~ Well G-16 Failed its MIT on 8/4/97. The well will be repaired during the '98/'99 Grayling Workover Program. Unocal requests a UIC Waiver~until 1999 summer end to complete repairs to the well. Form 10-403 Rev 06115188 G-16 Perforations ATTACHMENT TO APPLICATION FOR SUNDRY APPOVAL, G-16 PERFORATIONS MD MD TVD Zone Top Btm Btm G-1 12 G-2 12, G-3 12 G-4 12 G-5 12 G-6 12 HB-1 12 HB-2 12 HB-2 13 HB-3 13 HB-4 13 120' 164' 275' 335' 520' 685' 845' 904' 005' 108' 172' 12,145' 12210' 12 315' 12 450' 12 610' 12,725' 12,890' 12 985' 13 088' 13 142' 13 270' TVD Top 9 057' 9 090' 9 173' 9,217' 9 350' 9 465' 9,571' 9,783' Amt Present Condition 9 076' 9 124' 9 202' 9 300' 9 414' 9 491' 9 601' 9,846' 25' 46' 40' 115' 90' 40' 45' 81' 83' 34' 98' Open f/Injection Open f/Injection Open f/Injection Open f/Injection Open f/Injection Open f/Injection Open f/Injection Cmt Sqz'd Cmt Sqz'd Cmt Sqz'd Open f/Injection Page I 'rUE !5: 59 hSSET GhS GRP Fh× NO. Unocal 90726..%~. 74 P, O1/18 909 W. 9th Avenue Anchorage, AK 99501 Fax 907-263-7874 907-263-7665 (confirmation) Fax transmittal To; Fax Number: Date: Subject: I ~/-' ?z;"~.' .... ,, ,,. Pages: Cover plus Comments: FEB-03-98 TUE 15:59 UNO~O~ R$$ET GRS GRP FRX t~O, 9072¢-~874 P, 02/I8 Unocal Corporation Agricultural Products 909 West 9'~' Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL ) January 29, 1998 Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Grayling G-5, G-16, G-22, Cr-36DPN and G-40 9-5/8 casing leaks. Dear Blair: Water-flow logs were run on G-5, G-16, G-22, G-36DPN and G-40. The rcsullz from these logs indicate poss~le lenks in thc 9-5/8" casing strings. Thc wells have bccn shut-in, Copies of the WFL interpretations with updated wcllborc diagrams arc attached for your files. Senior Reservoir Engineer Cook Inlet Waterflood Management Please return a signed and dated copy of this letter to document noti~cation for our records. Blair Wondzell Petroleum Engineer AOGCC Date FEB-03-98 TUE 15;',59 UNOCAL RKB to TBG Head st 41.$' Tree connection: 13.1e¢ UNO0~ f~$SET G~S ORP G-1 G-2 8tupected breach in inttltily (~ 12,220' WL, M. LIB rtn ~ 8/4/91 G-3 G-4 G--5 HB-1 NO, 9072~,.~874 P, 03/I8 Trading Bay Unit ~0~E: 12'j' 'bifl:bctweenDP& DILI Well # G-16 12.24' Diff. betweentbg& DP 5/8187 24.24' Diff, between Dm & tbs III I I I I II I IIII I I I I I CASE~O AND TLIBJA'O DRTAll, $~E WT GRADE COFrN ID TOP BTM. CMT HB-2 HB-3 HB-4 ETD = 13,4"2' TD ' 13,683" KB ELEV - MAX ANGLE · 48.48 ~ 11,087' G-16.DOC I ?,3/4" .312 wail Weld Surf:, 601' 13-3/8': 61 K-55 :Se~ Lock 12.$15 Sur~. ~S0' 9-5/8" 47 P-110 Bu~ 8.6~1 10,680' 1~416 9-3~" 47 N-80 BuR 8.681 8~03' 10.680' 9-5/8" 43.5 N.80 B~ 8.755 62~' 1503' 9-5/8" 43.5 N.~O BuR B. 7~ 5 ~4' ~' 9-5/8" 47 N-lO Bun 8.611 S~, 54' ~ 29 P-II0 ~ 6,]14 l l,~5' )3,663' ~ 29 N-~0 B~ 6. IM 5~, i 1,345' T' DV Colic 6l ~' 6174' Tubing: 34/2- 93 N.$0 s.L 2.m: o' 12,0n' 2-7/r 6,4 N. so s.L 2.~} 12,20~ Il Illl Il / I lntegdt7 Note: . ,, While in~ectin$ (~ 4 BPM, 2050 pea down tho 9-L/8 X 13-3/8 mnulus, I Tamp Log ran on 4/23/87 revealed injection to 6060'. Cml $qz'cL down the annulu~ w/g00 sx of clm 'O". Noted PBU on annulus on $/!/87, ble, d o~ built buk-uo lo 800 md. jE~,bli~hed no Jaja;teen r~o (& 2000 pea on 5/2/8')', JEWELRY DETAIL NO. Depth ID Item 41.5 I 12,042' 2.7~ 2 i 2,072' 2.406 3 12,073 3.25 4 12,076' 3.25 5 12,016' 2.441 6 12,087' 2.76O 7 12,051' 2.~ 8 12,209' 2.441 9 12,237' 2.441 i o ! 2,773' 2.406 ! ! 12,774' 3.2~ 12 12,771' 3.2~ 13 13,816' 2..11.t 14 12,845' btm 12,1146' 3-1/2" CIW St~ialeu Tubin~ l~nser Otis'XA" $1~ Siva Locater Smd Amy. wi I.&' B~k~ Model "DB" Perm I~'. 8032 8~el Bo~e Ext. Crosiover. 8ell Bore Ext. Box X 2.7/8" Seal Lock Pin Crmsover, 2-7/1' Sell Lock Box X 3-1/2" 8ell Lock pm 4jt~ o1'3.1/2", 9.2#, N-10, ll0C, Seal Lock TbS Ctouovet, ~.1/2' Sell Lock Box X 2-7/1" &nj Leek Pin Teledyne.Mede lqow Mm(kal Local(x ~! A.lay w/11.69' or,alii. B~u~r Model "DB" P~. 12,7:50' 80-32 Sell Brae Ex1. eric "X" ~ofile Nipple WLBCI FISH Cmt Rate, er ~! 1/74 ~1 13,462' Junked Pict 3/30/71 (~ 1;,412 Cmt Retainer 4/2/71 (~ ) 3,412 8TIMULATIOHS Acldiza ~ 4~0 gals ~ 12-3 mud ~M & ~ ~11 Of E-OS I~V~I. 73~74 ~ Fracture 811muleted w/13,5~ oF ~nd inlo ~. 7/2~74 ~ Acldize ~ 4~0 gala of 15% HCL & 10,~ gals of t2-3 mud acid. ~8 ~ Acldlze ~ 16~ gale of 7.~% HCL ~/17 "O" Zone AcldEe ~ 35,700 gals ~ 12-3 ~d a~d. 5/3/ll "O" [one SLICKLINE WORK Tagged XO w/2.72" OR 1/1/97 ~ 12,079' WLM (12,086' MD) Tagged ob~lmclion wi 2,23" (3R 813/97 (~ J2,2~0' WLM 2.2S" LIB showed deep gouge1 o~ side & smaller In middle 113/97 (~ 12,220' WLM ACCUm UI! Zone Top Btm Amt SPF Pelf Date "0-1 12,'~to' t2,14r 26' 12 ..... 4~t~.t O-Z 12,1S4' 12,210' 4l' 12 4/26/81' O-3 12,2T6' 12,316' 40' 12 4/26/87 G-4 12,$36' 12,450' 116' 12 4126/B7 0.6 12,$20' 12,110' IW 12 4/26~UT 04 12,ee6' 12,726' 40' 12 4;25187 He-1 12,848' 12,800' 4S' le 4~r~07 HB-2 12,004' 12,086' 81' W14~74 HB-2 12,00r la, esr 8~' e/t4/74 HB4 13,108' 15,142' 34' 1/14/74 1'!11.4 13,17Z' 1%270' ~e' 20 4/21/17 Preeent Condition ii i ii i i i open # Injection ' open fl Injection Open fl Injection Open fl Injection open fl Injection Open I1 Injection Opefl fl Injection Cml Sqz'd cmt 9qz'd Cmt ~qz'd Open fl Injection "~EVISED: $/3/97 DRAWN BY: SLT FF..B-03-98 TUE 16:00 UNOCAL ASSET GAS GRP FAX NO, 9072837874 V. U4/1U .r. UI A GEOQUEST 500 W. International Airport fid. Anchorage, Alaska g2518 FAX COVER SHEET DATE: Februa~ 3, 1998 TO: Hal Martin/Chris Ruff UNOCAL FROM; cc: Rob North GeoQuest IC$ G-16 WFL Results TIME: 10:48 AM PHONE: 907-263-7675 FAX: 907-263-787~, PHONE: (907) 563-1597 FAX; (907) ,~62-8621 Number of pages including cover sheet: 2 Message Hal & Chris, Attached to this cover letter Is a log presentation of the WFL results for G-113, Below is a brief discussion: With the tubing to 7" annulus open during Injection the well was retumlng 1000 bbls to the surface, This flow Is originating at the eliding sleeve at a depth of 12042 feet as no flow was Indicated just above the packer at 12073 feet. With the annulus closed a reduced flow rate of about 100 bpd Is Indicated moving up from below 12110 feet, This flow appears to be leaking past the packer at 12073 Into the tubing x 7" annulus where It continues up to a point between 6500 and 6300 feet where It exits the 7" casing, No further up flow was seen above this point with the annulus closed. Down-flow measurements indicate a hole in the tubing between 350o and 4000 feet where flow ia measured in the tubing x 7" annulus, This flow appears to continue down [o ~6400 feet where It merges with the up-flow, exits the 7" casing and flows down the 7" x 9 518" annulus. This down~flow continues down past 12100 feet, Interested In your comments, Regards, Rob... Alaska OII a Gas Cons. Commissbn Anchorage FEB-03-98 TUE !6:00 UNOCAL hSSET GAS GRP F/~X NO. 90726.9LZ874 P, 05/18 ,,~ umu~r~r rna r r_.u-u,~-~u l Ub t U: U 1 UNOCAL ~$$ET G~S GRP ~"~-,,,. · UNOCAL ) i ii i iii ii RKB to Tt30 Hngr = 42' Tree COnnection: Dual 3" 5,000# IOO~& 2S00' SIZE 13-3/T' 9-5/8" 7" TubtnE: LS 3-1/2" SS 3-1/2" B 2 Suspcct tb§ partcd @ 11,329' lB ran on 8/1/97 I SUSpC~ tb§ parted @ IB ran on 6/10/95 KB ELEV = $9' TD - 13,479' ETD - 13,354' MAX HOLE ANGLE - 48.36° G.36.DOC F~X NO, 907263.~74 P, 06/18 Trading Bay Unit Well # G-36DPN Completed 12/5/87 i i iii i i i i i lin WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 54.5 43.5 & 47 29 9.3 9.3 K-55 Butt 12.6 ! 5 N.80 & S-95 8rd LT&C 8.835 N-g0 grd LT&C 6. ! R4 N-80 S.L & D$$-HTC 2.992 N-80 $.L 2.992 Sur£ 5307' Surf J0,874' 10,354' 13,479' 0' 12,586' 0' 10,281' NO. ,, , Depth 42' I I III A 10,215' B 10,249' C 10,266' D 10,279' E 10,280' btm 10,281' 10, ITS' 2 10,249' 3 10,318' 4 12,467' 5 12,500' 6 12,501' 7 12,505' lg 12,$12' 9 12,520' 10 12,553' Il 12,585' btm 12,586' I III I IIIII I 2.75 JEWELRY DETAIL ID Item .......... Cnm~re~ DCB Duel 3-1/2" TObing hangers, SHORT STRING III III 3-1/2" Otis "XA'; Slide.8 Sieove 9-5/8" Otis "RttD" Dual Packer 2.635 3-1/2" Otb "XN" Nipple, 2.75 01;,, Ball Catcher sub WLEO LONG STRING 2.75 3-1/2" Otis "XA' Sliding Sleeve 9-5/8" Otis "RHD" Dual Packer 2.75 3.1/2" Otis "XA" Sliding Sleeve 2.75 3-1/2" elis "XA" Sliding Sleeve Otis $traiflht Slot Locater w/4' speoer, 5' of seals & mule shoe 4,00 Otis "WB P~m PI~ 4.00 Otis Seal Bore Ext. 01is Mill out 15rtl. Crossover, 4-I/2" X 3-1/2" 2.75 3. !/2" Otis 'X" Nipple WLEG Retrievable Bridge Plug SLICKLINE TAGS SS "XN" wi'TX" plug leaked LS Tagged Fill Tagged obstruction (parted tbg) Tagged obstruction (parted tbg) WIRELINE WORK WFL ran on I/ STIMULATIONS Aoidizcd w/5% HCL & 12-3 Mud acid 8/]2/73 @ 13,364' 7/31/97 (~ 10,266' 11/19/88 (~ 13,270' 6/10/95 @ 12,507' 8/1/97 {~ 11,350' 8/! 8/87 West Forcland "O" Zotle ....... . ..... ','PERIr-6RATiON DATA .............' ' ' ' ' ' . Zone Top ,, , Bm Amt SPF Last Opt, Present Condition G-l_ . 1t,070' 11,110' ....... 40' ..... ...j. 12 ,.F1..4~.7 open f/ InJi~lion G-2_ 11,124' _1.1,!86' ..... 62' 12 ....... ~14/87 Open it Inle~m ~_-3_ t 1,2t2' 11,285' ,.. 53' 12 8/14(87 . , Ojgo. n f/lnJeetlon _ 0-4 15,28Z , ,11,385' 103' 12 _. ,~/14t87 Ol~nit!n.i~-Itm_ _ _ G.5 11,d92' 11,57~ 83' 12 8/~4/87 Open it InJe~io~ G-8 11.._848/ 11,8T/' _ _ 2~__ 12 8/14/87 Open it InJeotlm .... WF-1 12,684' 12.78Z 9ff 12 8/~187 open f/InJeetlo~ ~w.2 _ ~2,~ ~2,92~ ......... !;r j ~2 Wsl~ o~nitlnl, don WF-3 J_~_ O~n_f/Inledon WF-4'/ ¢,96r 1%096' 12~ j 12 ........e/6/87 13,_1,50' 13,220' 70' I 16 8/5~87 ~P ~l_.e~fo. ~a=~, ~,2~ ....~ 2.2X~ ...... .,', ~__.~_f a o/a/a? oo~. r/b~oc__ao. ..... .___3 ....... ~ REVISED: 8/4/97 DRAWN BY: SLT FEB-03-98 TUE 16:01 ·., UNQO~,. _R,~S..EoT..C, RS 6RP P, 07/18 §00 W. International Airport Fid. Anchorsge, Alsska BS§18 FAX COVER SHEET DATE.' February 2, 1998 TIME: 2:20 PM TO: Hal Martin/Chris Ruff PHONE; 907-263-7675 UNOCAL FAX: 907 -2 63 -7874 FROM: Rob North PRONE: (907) 563-1597 GeoQuest ICS F/t~X: (g07) 562-6521 RE: G-#36DPN WFL Results Number of pages including cover sheet: 2 Message Hal & Chris, Attached to this cover letter is a Icg presentation of the WFL results for (3- 36DPN. Below is a brief discussion: With the tubing to g 5/8" annulus open during injection the well was returning 940 bbls to the surface. A rate of 256 bpd is shown to be leaking past the dual packer at 10249 test. This rate increases at the station at 10205 feet indicating a significant leak In the short string sliding sleeve at 10215 feet. An addilional small leak was indicated in the long string sliding sleeve at 10178 allhough this Increase le near the resolution of the WFL measuroments. With the tubing to 9 5/8" annulus closed no flow was seen leaking up past the dual packer at 10249 however at rate of about 200 bpd appears to oflgtnate at ihs LS eliding sleeve al 10178. This up-flow continues up the lublng x 9 5/8" annulus until between 5000 to 3000 feet where It exits the 9 5/8" casing. An additional up-flow was measured at 10500 ff which may be flowing up the 7" x 9 5/8" annulus. Down-flow possibly in the tubing x 9 5/8" annulus is seen at 500 and 2000 foot. This flow appears to exit the 9 B/8" casing between 1000 and 2500 feet e, nd continues down outside the 9 5/8" casing past the lowest WFL station at 10550 feet.. I plan on delivering color copies tomorrow afternoon, Regards, Rob... r~.u-u~-u~_'l'U~, ,,~,,,16:02,~,,~ UNOOaL~..~., ,aSSET GaS GRP F~× NO. 90728.~L~.8~74 I.I.,N, ~,~ LiiIi~ F al~F ri'lA , P, 08/I8 r, Ur' · UNOCAL, TBU G-36DPN, TRADING 8AY UNIT, WI=L, 25.dan.gS, (gBO11) L_ j o.o ,~.o n.o ,oo., o.o ,~.o I o.o '.. ~,.~ ,,~ .... , ~.. ~, .%~ ', .,. . , ~. I,'1~ ~, , ; --;,,, "' , ': , ~ L~ ,',1 I I !~.';1~1 ; -- , ; -[- FEB-03-98 TUE 16:02 UNOOAL ASSET GAS GRP UNOCAL ) i i i RKB to TBG Hngr - 48.93' Tree connection: Dual 3" 5,000# 9eS7' k 10 I?ll'-If}l' 1711'-II'11' 0711%1713' 13 9119' _ NO, 9072~874 IIII I III IIII CASING A~L) TUBING GRADg CONN ID TOP 16" 75 13-3/8" 54.5 9-$/8" 47 9-5/8" 47 9-5/8" 43.5 9-5t8" 40 9-5/8" 47 T' 29 P, 09/18 Trading Bay Unit Well # G--5 Re-Completed 9/16/87 II II I BTM. CMT 9-5/8" DV Cella' .................................................. 5" Scab 18 N-gO Buu l'ublnK: L,I 3- i/2" 9.3 N-80 8.L. 2.992 8..t 3-1/2" 9.3 N-80 3.L. 2.992 -- 6/2~/95 (~ 9175' WLM W/ZY'IB 8/9/97 (~ 9175' WLM w/1.9" OK ]-55 Butt Sud'. 591'[ ! 330 Jx K-55 Butt t 2.615 Surf. 5307' 24~ u P-1 l0 Seal L~k 8.681 851P' 965T 3~0 ~ N-80 ~eal L~k 8.68 i 692~' 8519' " N-80 5esl L~k 8.755 ~ ! S 7 692~' " N-a0 ~1 Lo~ 8.135 ~' 5 ! 87 N. 80 Seal L~ S.681 8~ 79' N-80 8rd LT&C 6. 184 95~' 10,~02' 2~ sn 4]76' 4~78' 9719' 9803' 0-2 0-3 0-4 J[~ 0715' -! / ~ I, [~-13.75" ~Jt on ' _ ,, F ~5'~ TO - 10,31Z' ETD = 9,~65' HOLE ~GLE = 20.13° ~ 2600' MID PERF ~GLE = 6.5° (3-5 .DOC 0' 12,586' 0' io,28r I I Ill I ~gWELRY DETAIL rio, .DePth ..... =: .rD Item 48.83' Cameron I0" X SM, ~1 3.1/2" SHORT STRING B 9119' 9J/r B~w ~ PKk~ C 91~' B~ H~T~p D 9162' 2.635 3.1/2" ~ '~' Nixie, 2.75 b~ 91~' ~G S~O I ~OS2' 3.1a" ~is "~" Slld~ Sle~e 2 9119' 9-5/8" B~ ~1P~ker ~ 9SSO' 2.7S 3-1~" ~is "~" Slid~ Sle~e 4 9~84' L~or Seal ~. 5 9587' 4.~ B~er 6 959l' 4.~ B~ ~l B~ ~., 9' long 7 96~' ~, M 3-1/2' 8 ~! I' 2.7~ ~is "~ ~ofllo Ni~l= b~ ~3Y 1 ! 9619' 4.276 J" 18~, N.I0 12 9~ 4.~ ~t La~ Seal ~. !} 9tOY 4.75 X 4.~ ~ 98o6' 33 Tubin~ hin~er. FISH 2 Junked Retainer 9/16/71 ~ 10,244' Junked P-,~alner 8/12/72 ~ ! 0,240' Wire line tools, 16.~' length 6/6/95 (~ 9274' SLICKLINE TAGS LS Tagged obstruction, metal protruding f/sido oftbg, wi 2.Y' IB 6/26/95 ~ 917~' WLM Tagged obstruction w/1.9' GR 8/9/97 (~ 9181' WLM WIRELINE WORK WFL ran on 1/22/98 indicate s csg leak ~ or near DV collar (~ 4376'. [ndieations ofmultiple tbg leaks in or both sting from 2400' to 2650'. STIMULATIONS Acidized w/2-1/2% HCL & 12.10 ldud aoid 11/18/71 B-I, B-2, B-3 & B4 PRRFo~TioN DAT,~· ........ Zone Top, Btm A'nt SPF LastO~'. PteemtCondltion ..... b-~ s..2~ o~:.~~' ,~ .... 'W.'mf _ ,, ..~ 6,~ 9~] ~ 4 1~61 ~nfl~bn G~ 9,4~ 9,~0; ~.~ 4 ,. 9~81 ~nfl~n ........ ~3~4 e,~ 9,~Z 1~ ...... 4 Wll/e7 · 4 9,871' 9.~ ~ 4 t~81 ~~on ~4 9,~ 9,~ 23 4 .... W1W87 ~nf/IN~on ..... REVISED: 8/11/97 DRAWN BY: SLT FEB'03-98 TUE 1 UNOORL R,,S,$ET C-RS GRP FFt}~ NO, 1' riP, i~IW, 9E262.zS,~4 I UI" :, UO P, 10/18 r. UI ~00 W. International Airport Rd. Anchorage, Alaska 99518 FAX COVER S HEET OATllh January 30, 1 gg8 TO: Hal Martin/Chris Ruff UNOCAL FROM: RE: CO: Rob North GeoQuest lOS G-S WFL Results TIME: PHONE: FAX: PHONE: FAX: Number of pages including cover sheet: 2 Message 12:18 PM 907-263 -7675 ~07-263-7874 (907) 1563-1597 (907) 562-6521 Hal & Chris, Altached to this cover letter is a Icg presentation of the WFL results for G-5. Below is a brief discUSsion: With the tubtng to g 5/8" annulus open during injection the well was returning 1043 bbls to the surface. This flow appears to be coming in small part from the L$ sliding sleeve at 9082 and mainly from the SS sliding sleeve at 9051. No flow is seen coming up past the packer at 9119 feet. ,. With the tubing to 9 5/8" annulus closed no up-tlow was seen in the well, Inslead down-flow begins between 2400 and 2500 feet Indicating at least one of the tubing strings is leaking in this interval, Increases in the down-flow rate between 2400 and 2650 Indicate the possibility of multiple leaks, This flow continues down the tubing x 9 5/8" annulus to around 4000 ft wt3ere changes in velocity Indicate it possibly exits into the g 5/8" x 13 3/8" annulus and continues down. Between 61500 and 7000 feet the down-flow stops indicating the flow has exited into the formation, I hope to have the G-40 and G-36DPN interpretations out shortly. Regards, Rob... ~h_.~-U3-98 TUE 16:03 FED- r'-~flO IIUI1 IO~UO UNOORL R$$ET ORS C-RP FR× ~40. 907283~7,,8,74 P. 1I/'18 ~umber~er ~flJ{ I',IU, II:tUI' ~U~J Ii. 02 UNOCAL, TBU G-5, TRADING BAY UNIT, WFL, 21-Jan-98, (gB011} o i o o tJ~ ArctJI. O;en U~ A.~. C~e~ 0~ fu~t ~ , ,~,i ~E~l , ,, 2o~ ;:;!:i" · , 4: *, ! ~ ' ,, . :;;{ : 'i ""'L · ~1 ~',' i, --' ~ , " ,- [' "~ fl ' ~'Ii: ~,[' il;. 4~ ':~ ~ "~ ~ ' -~ ' :' '~"~i / - O000 ~ ;. ~ -~ . ,; : ~ , , ,, ,,...,,,,.. [: ,:: 4';' FEB-03-98 TUE i6:04 UNOCAL ) RKB to TBG Hngr = 4tl.6' Tree connection: Dual 3" $,000# UNOCAL ASSET GFiS GRP 1112~13 Obstruction in th§ ~ 10,05~ G-1 G-2 G-3 G-4 I-1 1-2 I-2 -= 8-5 TM of Junk · 11,254' RT to MSL ELEV ' TD = 11,336' ETD = 11,264' MAX HOLE ANGLE = 34.$1~ 4200' FAX NO, 90728.--'~874 CASII~C AND TU]nNG CTXiL ~' GRADI[ CONN ID TOP P. 12/18 Trading Bay Unit Well # G-22 Completed 5/6/90 MD TYD BTM 26" I" wall 20" 94 13-3/8" 61 & 68 9-515" 47 9-518" 47 9-5/8" 47 Tubing I,S 3-Iff' 9 2 SS 3-1/2" 9.2 24.0 Sm1'. 360' Butt 19.124 Surf. 629' H-40 Buu 12 415 Surf. 5548' N.B0 Butt 116111 Surf 7016' P. I 10 Butt 1.6B I 7016 I 0,017' 3.95 Butt 8.681 10,057' I i,3H' N-II0 Buff 2.992 0' I 0,$U' N. gO Butt 2.992 0' I 0,037' 6231' 8915' 99~4' G-22 dwg.doc Fill ~ 10,480' NO. D.¢h 46 60' A 9951 B 9994' C 10.030' D 10,036.67' btm 10,037.35' I I 9960' 2 9994' 3 I0,03 I' 4 10,478' 5 10.510' 6 DP MD 10,507' 7 DPMD 10,512' I! 10,550' 9 10,582' btm 1o DPMD 10,9~8' 11 DPMD 10.973' 12 DP MD I o,flo' 13 DP MD 10,981 btm 10,98Z30 JEWELRY DETAIL ID lttm Cameron DCB Dual 3.1/2" Tubir~ hanger. SHORT STRING 2.75 3-112" Otis "gA" Slidi~ BI,ye 2.90 9418" ~im "~' ~1 PKk~, SS Jot 2.63~ 3-1~" ~ '~' Nipple. 2.9~ _ .J mi ii 2.7t 2.90 2.75 2.75 2.9~ 400 400 2.75 2.95 3-1/2" Otis "XA' Shdtn~ Sleeve 9d/8' O~b *'RttD" Dual Packet' z-ur ~s"gA" $1idinf 3-112' O~is O~is 8~mi~t Slot Loc~r wi [96' ofs~ls & mule ~oe ~ "B~' Pe~ P~ (10J~' DII,) ~ 8,1Bo~ g~. ]-1/2" ~i~ "~ Nip~l~ 4.0 Oils "aw~r' P~ P~. (10,961' DIL) 2.99 Crossmmr 2.635 3-1/2" ~is "~' Nixie, 2,7~ wi P~ plul Z99 ~EO SLICKLINE TAGS ~ Tagged fill w/2.34Y' OR 12/9/97 @ 10,480' LS Tagged Obstruction in tbs w/2.125" LIB 12/10/97 @ I0,055' Tagged Obstruction irt tbs w/2.25" Swedge 12110/97 (~ 10,490' WIRELIh"E WORK WFL ran on 12/18/97 indicated a ±500 BPD cs8 leak behvc~n 4750' & 4800' originating from a pla' le~, STIMULATIONS 3 slagediverteracidjob: 138bblsof7-1/2%HCL200bblsof6 1/2%X l-l/2%mud I1121/89 G-Zone acid PERFORATION DATA .............. ............................. ~ ............................ T; ............................ '-J'"~%"-'-"" "'-'" i ~' I .......... IJi~ ~"~ ........... ~i .................................................... Zone Top am J Amt i S la: i LastOpr. lPte,entCondltion .... ~~'~ ........... ~;A";'""i ........... ~ ...... !" ....... '~ ........ ['"'"'~.'..' ....... i'~Z~_'"'""i~;a ................... ::~~~= ...... ~,,~..:.i, ......... ~i~. ..... !. 4 i ','~' l'~,;a,,~ ....... ..~........J ........ ~,~lo _.'E..,4m i ~ j ..... ~i .................. '~ig"'"i~fi'~ii~' .................... ..................... =6 ~ ......... ~ .... fif~'~': .................. ~i ............. ~ .......... 4 .......... ; ....... '~"4q'~ .... ; '6~"i~ ii'i~'~i'i~ ~ ........... .... 'g~' ....... :'"'~'~ ......... i ............ ~,r~" .......................................... ~ ................................................... ~ .................................................... j 34 ~ S&4 Yt'Fffllg jCDenf/Injeeton B-2 '0734 ...~¥.[ ........ ..~<~!:::.:::::::::::::::::::::::::::::::::::::::::':'i;'.':":~'~ ........ '"' REVISED 2/3/98 DRAWN BY: SLT FEB-03-98 ~TU~E~ 16'05 · · .o · I / " F~× NO. I llII ilVl P, 13/18 500 W. International Airport Rd. Anchorage, Alaska 99518 FAX COVER SH DATE: January 14, 1998 TO: Hal Martin UNOCAL FROM: RE: cc; Rob North GeoQuest lOS G-22 WFL Results EET TIME; 6:16 AM PHONE: 907-263-7675 FAX; 907-263-7874 PHONE~ (007) 563-1697 FAX: (g07) 562,-6521 Number of pages including cover sheet: 3 Message Hal, Attached to this cover letter tea Icg presentation of the WFL ,results for (3-22. -, Below is a brief discuss[on: ,. :., The WFL Up Flow rates were calculated for the tubing x 9 5/8" annular area,., Thls flow appears to originate from a leak In the packer at 9994/and-continues, up until it exits the g 5/8" casing between 4800' and 4760'. An additional'small. · ," leak out of the 9 5/8' may be Indicated by the drop In Up Flow rata between .. 6000' and 5500'. The WFL Down Flow ram were calculated for the 9 5/8" x 13 3/8" annular area . from surface to the boltom of the 13 3/8" at 5548'. Below Ihls point the area was assumed to be the full g 5/8" x 12.25" OH annulus, Increase or decreases In this annular area would have a corresponding effect on the calculated flow rates, The data Indlc~tes Down Flow starting between 1800' and 2000' and continuing down beyond the last station at 9500'. The possibility exists that the indicated Down Flow may be in the tubing x 9 5/8" annulus from 2000' to 4750' at whtch point it converges wilh the Up Flow and exits the 9 5/8" through the same point and continues down outside the 9 5/8'. The tubing spinner surveys both show an unexplained drop in inJeollon mia below -1000' which may best be explained by a ID reduction above this point (scale?), The Long String survey shows an additional alight drop Just below 1500' which could account for the start of the WFL Down Flow indication mentioned above. It should be noted that the spinner Injection rate measured in the Short FEB-03-98 ~T~E., 16:05 V !.11% I ~ t..,&/ I ~ UNO, rQ~,' R$$ET C~R,.,q C-12P FRX NO, 9072P:~.,874 P, 14/'18 String (~6000 BPD) Is greater than that of the Long String (-5000 BPD) which Is in opposition to the surface reported injection rates (SS ,.- 3670 BPD, LS = 6118 BPD). The spinner data appeam to be verified by the temperature data which shows cooler temperatures In the Short String which would be expected at a higher injection rate. Hopa thfa gives you some more food for Ihought. I am Interested tn any additional InformatiOn or Ideas you may havg. Glva me a call when you've had a chance to look it over. Regards, Rob... FEB-03-98 TUE 16',05 UNOO~J~ R$SET GR$ GRP NO. 9072~874 P, 16;/18 UNOCAL TBU ~-~., TRADINg BAY UNIT, WFL, 17-0EC,-6'/, 1960tl) Outmlde I I/S' ~ ,, L8 91d~nee 68 IpP~e~ II ~ ~ I!g '~-7,. (,,,,,). lIf~ ,: lii~i ~__,.~_ _ FEB-03-98 TUE 16:06 UN0~0_~.L ASSET GAS GAP ' 'UNOCAL ) ' FAX NO, 9072~7874 ?, 16/18 Trading Bay Unit Well # G-40 Completed 4/26/90 RKB to TBG Hngr - 40.8' Tree connection: Dual $" S, O00# $IZg i iiiiiiii i i 16" '/S 13-3/8" 68 9-S/{" 47 9-S/I" 47 9-{/{# 47 9-$/~" 47 9-{/8" 47 Tubing: L8 3-1/~" 9.2 SS 3-1/2" 9.2 C G AND TIYBIaNG DETAIL ..... I~D MD T~D BTM G~E CO~N ~ TOP D~I. K-SS Butt I S.124 Surf. 1 F26' S-g0 & K-SS Bu~ 12.41S Surf. $121' K-55 Butt 8.681 Surf 47' ~-80 Butt 8.681 47' 976~' 9220' ~-9S Bu~ 1.6~ i 976~' 10,929' I 0~00' N-80 Butt 1.681 10~929 11,146' 10,~00' S-9~' Bu~ L681 11,14~' llJ~2' 10,60~' N-80 BuR 2.992 0' N-80 BuR 2.9~ 0' 9827' ~0' 816/97 shows th§ to be obiongcd 2,72" X !~.ss" @ ~,on' B-1 B-4 NO. III. A B c I I _ Illll I Depth ..... ' 40.S0' I 9760' 9?96' 9~2S' btm 9S27' II Il I 9762 10,348' 10,3eS' DP ~ 10~71' DP ~ b~ 10~90' 10,42~ JEWELRY DETAIL ID . Item Cameron DOB Dull 3-'1/2" Tublng h,nler' " SHORT STI~NO 2.?S 3-1/{" Otl~ 'XA" Slldlnl Sleeve 2.90 g-S~" O~a ~' Dual Pacbr, Ball Catcher Sub ~NO II I IBII I ' 2.75 3-1~" PUl "~" Sliding Sleeve 2.90 9-S~" OUI "~' DUll 2.?S J-aa" OW ~ Slldlnl SleeYe 2.95 Pall ~liht Sl~ ~CltOr 4.00 O~ "B~' P,rm P~ 4.00 O~ Seal Bare EzL 2.7S 3.1~' Offs 'X' Nipple 2.9~ T 9 =- WF-6 --- W;.T RT to MLLW ELEV = 103' TD = 11,267' ETD" 11,143' MAX HOLE ANGLE = 27.2' G-40.DOC SLZCKL/NE TAGS SS Tag "XN" w/2.72" GR 815/97 ~ 9813' LS Tagged obstruction wi 2.72" GR & 2.72" LIB 816197 (~ $,012' Tag fill wi 2.25" Ll]3 8/7/97 WIRELII~ WORK · Spinner ran on 1/22/98 Indicates tbs leaks ~ 9812' & 10,125' · WFL ran on 1/23/98 indicates csg leak between 3250' & 3.t50'. · WFL indicated multiple SS tbs leaks, sidg sire (~ 9760', tbs Jt between sidg sire &pkr and between 1200' to 3400'. STIMULATIONS 2 atag acid Job wi dlverter, 50 bbb ofHCL i 75 bbb of 6-1/2% X 1-1/2" mud ecJd 2 stag acid Job, 40 bbb ofHCL & 135 bbb of 6-1/2% X 1-1/2" mud acid 3129190 West Forland 3/29/90 H]{.I & 2 Accum. Date Zone , T,o,p ,.B, tm Amt, , SPF Last Opr, Present CO,,nd!lion,, , 9.es0' s,ee2' _ ...... T 4 ' ' ' ~/201~0 Cmt 8qz si{L1 e,e9_2'._" . 1,928' 34' . e 31~6/(IO open fl I.njeCtlon ... 9,934' 9,S38' 2'. ,. 4 3~19/90. Cmt 8qt_ . . !0,111' _1.0,t13'' 2' 4 .... 3/la/So '¢mt Sqz BM 10,128' 10,208' '" so,.'.' e .... 312e~10 0 .l~nfl Jn~actlo,,r),, lO,2.1e' !o,220' .. 2' 4 3J16/t0 Cmt 9qz ...... 10,465' I~,4b'/' .. 2.. 4 3/t?110 Cmt 8qz ..W~:'-2 10,625'. · . 10,656'. ..... 40' 8 ..... _3J2{J10 Open fl Injection WF4 : . 10,Se0' 10,770' 90' S 3Y26Yg0 Open fl InJq.ctlon WF -6 10,g35' 10,868.__.' .... 55' $ 3~..6~iO (~pen fl Inle;tlon WF -4 10,.g..'lS' lO,eT,2,' ST e .... 3tzg/so Open fl Injection wF ~7 10,$g3' 1.~,040' .. 4T ~8 3/2~/$0 Open fl Injection . 11.~0~.._2..; .... J t!,0~i', .... 2' . ...... 4 ., 7117100 Crate(ar_ . _ ..... ' '-'" · ..... IU~VISED: 2/2/98 DRAWN BY: SLT - ,--- r". .. FEB-03-98 TUE 16:07 - ,,'flN-30-98 FRI 1 ?;03 UNOC~RL ,qSSET GRS G-RP NO. 9072~74 ~× NO. P, 17/18 P,O~, 500 W, International Airport Rd. Anchorage, Alaska gg518 FA X C'O V E R S H E ET January 30, 1998 Hal Martln/Ohfls Ruff UNOCAL FROM; liE: Rob North GeoQuest ICS G-40 WFL Results TIME; PHONE: FAX: PHONE; FAX: 3:44 PM 90?-263-?6'75 907-263 -'/874 (907) (907) 562-85;21 Number of pages including cover sheet: 2 Message Hal & Chris, Attached to this cover letter is a log presentation of the WFL results for (3-40, Below is a brief dis~'~'useion: With the tubing to 9 5/8" annulus open during Injection the well was returning 1040 bble to the surface. This flow appears to originate from the sliding sleeves at 9752 and 9760 In tl'm long and short strings. No flow Is seen coming up past the packer al §789 feet. With the tubing to 9 5/8" annulus closed up-flow continues at a reduced rate. This flow travels up the tubing x ~ 5/8" annulus until between 33§0 and 3250 tt where It exits the 9 5/8" casing, An additional up-flow Is measured across the lower packer at 10378. Down-flow In the tubing x 9 5/8" casing Is seen starling between 900 and 1200 feet. This flow continues down and appeam to exit the 9 5/8" casing In the same Interve, I as the up flow mentioned above (~3300 ft). This combined flow then travels down the 9 5/8" x 13 3/8"/OH annulus to the reservoir a! or below 10000 feet. Working on Q-36DPN now. Regards, Rob... ~.B-~S-98 TUE 16:07 UNO~ ~SSET GRS GRP FR× NO, 8079~'~874 ?. I8/18 .~ ..JAN-30-98 FEI 17:03 : ~,h,I;,.b~rg~r F~X' NO. 1~ 'q~30g P, 02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: 99' to MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box'196247Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface 8. Well number 1879' FSL, 1381' FEL, Sect 29, T9N,R13W,SM (Conductor 49, Leg 2) TBUS G-16 At top of productive interval 9. Permit number 977' FSL, 617 FWL, Sec 27, T9N, R13W, SM 68-109 At effective depth 10. APl number 364' FSL, 1403' FWL, Sec 27, T9N, R13W, SM 50-133-20162-00 At total depth 11. Field/Pool 258' FSL, 1507 FWL, Sec 27, T9N, R13W, SM ', McArthur River Field 12. Present well condition summary Total depth: measured 13,663' feet Plugs (measured) true vertical 10,129' feet Effective depth: measured 13,482' feet Junk(measured) ORIGINAL true vertical 10,012' feet Casing Length Size Cemented Measured depth True vertical depth Structural 376' 26" Driven 376' 376' Conductor 601' 17-3/4" 750ax 601' 601' Surface 5,960' 13-3/8" 2350sx 5,960' 4,568' Intermediate 12,416' 9-5/8" 1000ax 12,416' 9,249' Production 13,663' 7" 1300ax 13,663' 10,129' Liner Perforation depth: measured (See attachment)RECEIVED true verticalJAN 4 1998 Tubing (size, grade, and measured depth) 3-1/2" x 2-7/8" N-80 SL conn. at 12,821' ~lJa~ 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) Baker Model DB @12,750' (DIL) and Baker Model DB @ 12,048' Anchorage 13, Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 2/15/1998 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injector 17. I hereby certify tha~h,en ~regoing is true a~c~.~rei~to the. best of my knowledge. S ig n ed: ~ ~/,~,~/,~/~/~ , ~/~l J~t~e: Drilling Manager Date:/ - FOR COMMISSION USE ONLY I No. Conditions of approval: Notify Commission so representative may witness Approval.,, Plug integrity.~ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- ~O ~.~ Approved Copy Returned ._ . ~! cg'~i o)~ Original Signea lJy · [ I David W. Johnston Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Grayling G-16 Perforation Record Measured Depth Tree Vertical Depth 12,120-12,145' 9,057'-9,076' 12,164'-12,210' 9,090'-9,124' 12,275'-12,315' 9,173'-9,202' 12,335'-12,450' 9,217'-9,300' 12,520'-12,610' 9,350'-9,414' 12,685'-12,725' 9,465'-9,491' 12,845'-12,890' 9,571 '-9,601' 12,904'-12,985' 9,609'-9,663' 13,005'-13,088' 9,676'-9,730' 13,108'-13,142' 9,742'-9,767' 13,172'- 13,270' 9,783 '-9,846' Grayling G-16 BHP and Proposed Workover Fluid Static BHP G-Zone: Hemlock: 3300psi at 9057'TVD 4000psi at 9570'TVD Proposed Workover Fluid Maximum Pressure Gradient: Workover Fluid: .42psi/fi (Hemlock Bench 1) .44psi/ft (Formation Inlet Water +3%KCL) Unocal Alaska Business Unit Grayling Platform Well Grayling G-16 Injector AFE # 130075 Prepared by: Neil Magee Date:Il/25/97 Revision #1 ONOCAL0 No. Summary of Proposal Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) 1 Rig up on well 24.0 24 1.0 2 Check for tubing pressure and set BPV. 2.0 26 1.1 3 N/U and test 13-5/8" 5K BOP's 8.0 34 1.4 4 P/U landing joint and screw into hangar top. 4.0 38 1.6 5 Pull tubing assembly loose from top packer at 12,060' and monitor well. 2.0 40 1.7 6 Displace well with FIW and monitor returns through gas buster. 4.0 44 1.8 7 POOH laying down tubing 16.0 60 2.5 8 P/U 3-1/2" DP and RIH with packer milling assy. 14.0 74 3.1 9 Mill over packer 22"+/- 2.0 76 3.2 10 POOH with packer milling assembly. 8.0 84 3.5 11 RIH with spear and engage packer at 12060' 8.0 92 3.8 12 Pull packer assembly and parted tubing(?) at 12,220' 10.0 102 4.3 13 RIH with overshot dressed to recover tubing stub. 8.0 110 4.6 14 POOH with tubing stub and and seal assy from lower packer at 12,762' 10.0 120 5.0 15 Make up 7" RTTS and RIH to 12,100'. Pressure test casing to 2000 psi 8.0 128 5.3 16 POOH and lay down RTTS 7.0 135 5.6 17 R/U slickline. Make dummy run to check for access throt~gh lower packer 6.0 141 5.9 18 R/U Schlumberger and make gage ring run. 4.0 145 6.0 19 Run permanent packer on wireline and set at 12,000'. 6.0 151 6.3 20 Run 4-1/2" completion tubing with seal assy. 14.0 165 6.9 21 Displace well to inhibited packer fluid. 4.0 169 7.0 22 Stab seals in and space out. Land tubing hanger and test. 2.0 171 7.1 23 Run BPV and N/D BOP's 6.0 177 7.4 24 N/U tree and test to 5000 psi 6.0 183 7.6 25 Nipple up Flowline and have State Inspector witness MIT 4.0 187 7.8 26 Release well to Production and prepare to skid rig. 8.0 195 8.1 Grayling G- 16 Injecto~,, er. 1) 1/8/98 Proposed Workover and Recompletion Grayling -16 Injector Objective: It is proposed to workover and recomplete Grayling Well G-16. The well is currently a single string injector for both the Hemlock and G sand series. The objective of the workover is to repair tubing to casing communication and to regain access to G/HK intervals. The workover will consist of pulling the tubing string, milling over and recovering the uppermost packer and tubing assembly below, asses accessibility to Hemlock perforations and running a new completion. Pre-Workover Slickline Work: Prior to commencing the workover, slickline work was performed to determine the integrity of the 7" casing and tubing above the top packer. This entailed setting a "PX" plug in the "X" profile above the "XA" sleeve and testing the 7" casing and 3-1/2" tubing to 2400 psi. This indicated that there was slight tubing to annulus communication and a moderate annulus leak indicating a failed packer. A Water Flow Log will be run prior to commencement of workover operations to confirm the approximate location of the leak. Shutting in Injection: G-16 should be shut in several days before the rig work is to commence to allow for the well pressures to stabilize. Attempts should be made to bleed off any residual pressure prior to commencing the workover in order to eliminate the need for killing the well. Workover Procedure: . Skid rig over well R/U hardlines to casing annulus and line out to choke manifold. Pressure test lines to 80% of working pressure. (Lines WP to be 5000 psi.) . Check for tubing pressure. If tubing has pressure, bullhead 1-1/2 times tubing and open casing volume below packer to kill well. If annulus has pressure open Otis "XA" sleeve at 12,025' RKB and circulate down tubing taking returns up annulus through to choke manifold. 3. Install back pressure valve. Have Cameron Rep verify that all pressure has been bled from all lines and all voids associated with the tree, seal flange, tubing hangar, tubing spool and any other potentially energized void immediately prior to removal. Grayling G- 16 Injector,. er. 1) 1/8/98 Nipple down production tree and flowline. Inspect tubing hangar top. Verify thread type and condition. 4. N/U BOP's . . o o . 10. BOP Arrangement: Annular Preventer 3-1/2" Rams Variable Bore Rams Blind Rams Pull BPV and install two-way check. Test BOP per Unocal and AOGCC specifications. Test rams 250 psi low, 5000 psi high. Annular 250 psi low, 3500 psi high. Complete Unocal Alaska BOP Checklist and Contractors Checklist and fax to office. Note: Notify AOGCC 24 hours in advance of BOP test. Hold Pre-Workover Safety Meeting. Brief crews on safety and environmental concerns and handling of NORM pipe. Recover two-way check. Make up 3-1/2" landing joint and engage hanger. (Hanger connection is reported to be 3-1/2" EUE top x 3-1/2" Butt bottom - Wellhead Schematic attached.) Monitor well for pressure. If well is stable back out hanger hold down screws and proceed to Step 8. Otherwise kill well with FIW. (Kill procedure to be discussed with Anchorage Drilling Supt.) Pick up hanger 10' and pull completion string free. Monitor well and circulate FIW down tubing (1-1/2 tubing and annulus volume) taking returns through choke manifold to ensure well is clear of gas. Note: Discharge returning fluid overboard or to Production as appropriate after taking samples and performing sheen tests. POOH laying down tubing. (Tubing is 3-1/2" N-80, SL conn. internally coated) Note: All tubing recovered to be handled and inspected for NORM contamination in accordance with NORM Guidelines attached. Report NORM readings on Morning Report. Note: Verify seal bore is 3.25" OD Make up Baker Model "DB" packer milling assembly as follows: Grayling G-16 Injector ,. er. 1) 1/8/98 6" OD packer mill with 1-1/2' long extension with 2.5" OD pilot, tungsten insert type blades with 3-1/2" Reg pin up. 2 ea. 4-7/8" OD Boot Baskets with 3-1/2" Reg box x pin Bit sub, 3-1/2" Reg box x 3-1/2" IF box Bowen lubricated fishing bumper sub, 4-3/4" OD, 3-1/2" IF box x pin Bowen Super Two fishing jar, 4-3/4" OD, 3-1/2" IF box x pin 9 ea. 4-3/4" Drill collars, 3-1/2" IF 3-1/2" drill pipe to surface 11. RIH with packer milling assembly to packer at 12,060'. 12. Mill "DB" packer. Mill top slips (22" to bottom of slip assembly) and continue milling until there is an indication of rubber coming back to ensure slips have been completely milled through. Circulate hi-vis pill as required to clean well. Circulate bottoms up and POOH. 13. Make up packer retrieving assembly as follows: 3.25" ITCO Spear (RH release) with 2-3/8" Reg box 2-3/8" pin x 2-7/8" API Reg box Stop Sub (5-3/4" OD Stop Ring), 2-7/8" AP1Reg pin x 3-1/2" IF box 3-1/2" Pump Out Sub, (No piston, used as drain sub), 3-1/2" IF B x p Bowen lubricated fishing bumper sub, 4-3/4" OD, 3-1/2" IF box x pin Bowen Super Two fishing jar, 4-3/4" OD, 3-1/2" IF box x pin 9 ea. 4-3/4" Drill collars, 3-1/2" IF 3-1/2" drill pipe to surface 14. Spear and engage packer. Pull free and POOH laying down packer and tubing assembly below. 15. It is suspected that the tubing is parted at 12,220WLM. Attached find wireline report and LIB impression which indicates possible parted tubing above GLM at 12,224'KB/WLM (12,025'KB on original completion detail.) Listed below is the provisional fishing assembly for the 3-1/2" or 2-7/8" tubing fish. Over-sized Cut Lip Guide Overshot Bowl 5-3/4" Overshot Extension, 5-3/4" Top Sub 5-3/4"OD, 3-1/2" IF box 3-1/2" Pump Out Sub, (No piston, used as drain sub), 3-1/2" IF B x p Bowen lubricated fishing bumper sub, 4-3/4" OD, 3-1/2" IF box x pin Bowen Super Two fishing jar, 4-3/4" OD, 3-1/2" IF box x pin 9 ea. 4-3/4" Drill collars, 3-1/2" IF 3-1/2" drill pipe to surface 16. RIH and engage fish. Pull fish free from Baker Model "DB" packer set at 12,762'. Grayling G- 16 Injector, er. 1) 1/8/98 17. POOH and lay down recovered tubing string. 18. Make and RIH with 7" RTTS to 12,100'. Pressure test casing above packer to 2500 psi for 30 minutes. POOH and lay down RTTS. 19. Rig up Pollard .125" slickline unit with wireline BOP's and pump in sub. Pressure test lubricator to 1000 psi. Make up and RIH with 2.1875" gage ring wireline assembly. Pass through tubing assembly below "DB" packer (Minimum restriction is "X" nipple 2.313"ID) and determine accessibility to lower Hemlock interval. Tag ETD and POOH. 20. Rig up Schlumberger. Note: Verify Schlumberger setting tool rig up Fill out Hot Work Permit for packer setting equipment Complete Unocal's Perforating/Explosive Safety Checklist before arming 21. Make 5.875" guage ring/junk basket run to 12,100'. Make up following assembly and set a minimum of 5' above 7" casing collar at approximately 12,000'. (EOT to be approximately 12,070')Ref log Baker Model "F" Permanent Packer (3-1/2" ID) Baker size 85-40 Seal Bore Extension (10' length) Crossover Sub 1 joint 3-1/2" Mod. Butt tubing Baker nipple with Otis Type "X" profile 1 joint 3-1/2" Mod. Butt. tubing Baker Wireline Entry Guide x 1/2 muleshoe 20. Pick up remaining completion as follows. Dope pin connections only using small paint brush with lead free modified dope. Rabbit tubing and pups on trip in hole. Baker 1/2 Muleshoe Guide Baker Locator Type Seal Assembly (10') 3-1/2" Butt box up 3-1/2" 9.2 lb/ft L-80 Mod. EUE Tubing Space out pup joints 3-1/2" 9.2 lb/ft L-80 Mod. EUE Tubing Double Pin 3-1/2" 9.2 lb/ft L-80 Mod. EUE Cameron DCB Tubing Hanger 21. RIH with assembly torquing connections to make up marks on buttress connections. Rabbit all 3-1/2" tubing joints with a 2.875" drift. 22. Stab seal assembly into packer while slowly circulating note pressure increase. Pressure test backside to 1000 psi. PU and displace annulus to corrosion inhibitor fluid. Space out for lbs string weight setting down on packer. Grayling G- 16 Injectm,, er. 1) 1/8/98 23. Land DCB tubing hanger and engage lock down screws. Test annulus to 2500 psi for 30 minutes. Test hanger body seals to 5000 psi. 24. Set BPV and ND BOP's 25. 26. NU tree. Recover BPV and set two way check. Pressure test tree and neck seals to 5000 psi. Recover two way check. Rig up surface injection lines. Perform MIT to .25 psi/ft x vertical depth of packer or 1500 psi whichever is greater for 30 minutes. (See attached guidelines and program.) Note: Notify AOGCC at least 24 hours in advance of pending MIT test. 27. Release rig. .3" KILL L[NE WITH TWO 3" 5M VALVES ! ,'i; KILL LINE FROM MUD PMP & CEMENT UNIT NIPPLE I 15-5/8" 5000 PSI ANNULAR PIPE RAMS ~ FLOWLINE 1;3-5/8" 5M FLANGE ~ DOUBLE GATE 5M BLIND RAMS L"'~I 13-5/8" 5M FLANGE i.._..~1 4." CHOKE LINE WITH ONE REMOTE ..; ,~ 1 MANUAL 4" 5M VALVE , B CONNECTEB TO CHOKE MANIFOLD I (SEE MANIFOLD DRAWING) i RISER 1,3-5/8" 5M FLANGE SINGLE GATE 5M 15-5/8" 5M FLANGE 10" 5M x 15-5/8" 5M ADAPTER I i i ii iii i i CAMERON 5M SPOOL 15-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNQCAL) · "DRAWN: DAC APP'D: GSB SCALE: NONE MIXING PIT 40 BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM /il. 185 BBLS VOLUME PIT TRIP TANK 4-5 BBLS 185 BBLS SUCTION PIT I I II ! ! 125 BBLS DEGASSER 67 BBLS J DESILTER i 24-0 BBLS SHAKER SHAKER --CENTRIFUGE RESERVE PIT 4-75 BBLS NOTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL INDICATOR WITH AUDIO & VISUAL WARNING DEVICES. EQUIPMENT LIST 1) RESERVE PiT 2) DEGASSER 5) (2) SHAKERS 4) PIT LEVEL INDICATOR (VISUAL & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS 8) DESILTER 9) CENTRIFUGE 10) MIXING PIT UNOCAL GRAYLING MUD PIT SCHEIvlATIC DRAWN BY: DAC APP'D: GSEI SCALE: NONE DATE: 11-30-89 TO GAS BUSTER /\ 3-1/8" TO DERRICK VENT TO WELL CLEAN TANK /\ 3-1/8" 4.- 1/16" AUTOMATIC CHOKE FROM CHOKE LINE AUTOMATIC CHOKE VALVES UPSTREAM OF CHOKES ARE 10,000 PSI (;;ATE TYPE VALVES DOWNSTREAM OF CHOKES ARE 5,000 PSI GATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM ., UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN' DAC APP'D: GSB SCALE: NONE DATE: 11/26/89 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: 99° ET to MSL feet · 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519- 6247 Service:~ Trading Bay Unit 4. Location of well at surface 8. Well number 1879'N-1381°W f/SE cor., Sec. 29, T9N R13W SM G-16 At top of productive interval g. ~r~ n~u~ 669' N - 1052' E fl SW cor., Sec. 27, T9N R13W SM ~ 7-232 At effective depth 10. APl number ' 432' N - 1327' E f/SW cor., Sec. 27, T9N R13W SM 50-733-20162-00 At total depth 11. Field/Pool 317' N- 1462' E f/SW cor., sec. 27, T9N R13W SM McAurthurRiver/Hemlock& G-zone , 12. Present well condition summary Total depth: measured 13,663' feet Plugs (measured) true vertical 10,129' feet Effective depth: measured 13,482' feet Junk (measured) true vertical 10, 012' feet Casing Length Size Cemented Measured depth True vertical depth Structural 376' 26" Driven 376' 376' Conductor 601' 17 3/4" 1850 sx 601' 601' Surface 5,960' 13 3/8" 2359 sx 5,960' 4,568' Intermediate 12,416' 9 5/8" 1000 sx 12,416' 9,249' Production 13,663' 7" 1300 sx 13,663' 10,129' PerfoLi;t~'ron depth: measuredR E ¢ E IV E D See Attchment true vertical ~? 5 1997 Tubing (size, grade, and measured depth) 3-1/2", 9.2~, N-80 (~ 12,805' Alas._ka.0il & 6as Cons. Packers and SSSV (type and measured depth) Baker Perm pkrs @ 12,048' and 12,750' ~ci~Qrage 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water I niection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Title: ~ ~-,'k'-, ~--~T','~,~.5,~ Date: '~t~-°~(.~'."(r O~1~ ) ro~af~p v' ' FOR COMMISSION USE ONL~''1' Conditions I: Notify Commission so representative may witness IApprov,~N/~ Plug integrity BOP Test Location clearancei ~77<._. '~ -.-' Mechanical Integrity Test ubsequent form required 10- t.(.(~C ~ · Approved by order Of the C .... Commissioner Date j n,~.9,. Well G-16 Failed its MIT on 8/4/97. Unocal tinuation of injection while the well is being evaluated for either a workover to replace the existing completion or a WFL to insure csg integrity. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE G-16 Perforations ATTACHMENT TO APPLICATION FOR SUNDRY APPOVAL, G-16 PERFORATIONS MD MD TVD Zone Top Btm Btm G-1 G-2 G-3 G-4 G-5 G-6 HB-1 HB-2 HB-2 HB-3 HB-4 12,120' 12,164' 12,275' 12 335' 12 520' 12 685' 12 845' 12 904' 13 005' 13 108' 13 172' 12 145' 12210' 12 315' 12450' 12610' 12 725' 12,890' 12,985' 13,088' 13,142' 13,270' TVD Top 9,057' 9,090' 9,173' 9,217' 9,350' 9,465' 9,571' 9,783' Amt Present Condition 9 076' 9 124' 9 202' 9 300' 9 414' 9 491' 9 601' 9,846' 25' Open f/Injection 46' Open f/Injection 40' Open f/Injection 115' Open f/Injection 90' Open f/Injection 40' Open f/Injection 45' Open f/Injection 81' Cmt Sqz'd 83' Cmt Sqz'd 34' Cmt Sqz'd 98' Open f/Injection Page I STATE OF ALASKA ALASKA 0~" AND GAS CONSERVATION L. OMMISSlON APPLICATION FOR SUNDRY APPROVALS 1. Type'of RequeSt: Abandon: Suspend: Operation shutdown: .. Re-enter suspended well: Alter casing: Repair well: Plugging: "Time extension: Stimulate': Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of operator ' ' 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: 99' ET to MSL feet , , , 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 Service:"X" Trading Bay Unit 4. Location of well at surface 8. Well number 1879'N-1381'W f/SE cor., Sec. 29, T9N R13W SM G-16 At top of productive interval 9. Permit number 669' N - 1052' E fl SW cor., Sec. 27, T9N R13W SM 7-232 At effective depth 10. APl number 432' N - 1327' E fl SW cor., Sec. 27, TgN R13W SM 50-733-20162.430 At total depth 11. Fletd/Pooi 317' N - 1462' E fl SW cor., Sec. 27, T9N R13W SM McAurthur River/Hemlock& G-zone 12, Present well condition summary Total depth: measured 13,663' feet Plugs (measured) truevertk~,al 10,129' feet--- ----., ,, ,,- Effective depth: measured 13,482' feet Junk (measured) true vertical 10, 012' feet Casing Length Size Cemented Measured depth True vertical depth Structural 376' 26" Ddven 376' 376' Conductor 601' 17 314" 1850 sx 601' 601' Surface 5,960' 13 3~8" 2359 sx 5,960' 4,568' Intermediate 12,416' 9 518" 1000 sx 12,416' 9,249' Production 13,663' 7" 1300 sx 13,663' 10,129' Liner Perforation depth: measured Tubing (size, grade, andmessureddeptn) 3-1/2", 9.2~, N-e0@ 12,805' ~;~-:F) ;5 1997 Peckers and SSSV (type and measured depth) Baker Perm pkrs ~ 12,048' and 12,750' ~ ~j~ ..& (~as :Col'is. 13.' Attachements "' Description summary of prO~l: Detailed operations program: ' 14~ Estimated date for commencing operation 15. Status of well classir,=ation as: 16. If proposal well verbally approved: ' Oil: Gas: Suspended: Name of approver Date approved Service: Water I niection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~) \ \ ~ -' ,o. co~.~ss~o. USE o.,2~ Plug integrity BOP Test , Location clearance Mechanical Integrity Test ubsequsnt form required 10- Approved.by order of the Commissioner .~,,:~ ~t~i Inhnefnn Commissioner Date Well G-16 Failed its MIT on 8/4/97. Unocal reqUests a continuation of injection while the well is being evaluated for either a workover to replace the existing completion or a WFL to insure csg integrity. ~,~,,,~vect GoP¥ Form 10-403 Rev 06/15/88 Ret~jrrt.ed ,,,.4 SUBMIT IN TRIPLICATE G-16 Perforations ATTACHMENT TO APPLICATION FOR SUNDRY APPOVAL, G-16 PERFORATIONS MD Zone Top G-1 12,120' 12,145' G-2 12,164' 12,210' G-3 12,275' 12,315' G-4 12,335' 12,450' G-5 12,520' 12,610' G-6 12,685' 12,725' HB-1 12,845' 12,890' HB-2 12,904' 12,985' HB-2 13,005' 13,088' HB-3 13,108' 13,142' HB-4 13,172' 13,270' MD TVD TVD Btm Top Btm 9 057' 9 090' 9173' 9 217' 9 350' 9 465' 9 571' 9,783' Amt Present Condition 9,076' 9,124' 9,202' 9,300' 9,414' 9,491' 9,601' 9,846' 25' Open f/Injection 46' Open f/Injection 40' Open f/Injection 115' Open f/Injection 90' Open f/Injection 40' Open f/Injection 45' Open f/Injection 81' Cmt Sqz'd 83' Cmt Sqz'd 34' Cmt Sqz'd 98' Open f/Injection Page 1 Unocal Nortt't Ama Oil & Gas Oivision Unocm C,3r~arat~an Anchorage. Al~xa Te~eanane tg0~ 278-76~a Ala.sxa Re~zon April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. JoI'lnSon: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your. needs. Yours very truly, GSB/lew GRAYLING DISTANCE &.DIRECTIONS FROM SE CORNER SEC. 29~ TgN, R13W CONDUCTOR "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 ll 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 G-26 1806 2,502,358.05 212,269.49 G-25 1810 2,502,358.77 212,273.94' G-24 1810 2,502,356.46~ 212,277.80 G-20 1808 2,502,352.20 212,279.28 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 = 60050' 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: 2 · LAT : 60050' 23.575" LONG =151°36' 4Z. 505" ' 2,502,374.34 212,196.66 2,502,376.65 212,192.79 2,502,380.90 212,191.32 2,502,385.11 212,192.92 2,502,387.30 212,196.85 2,502,386.45 212,201.28 2,502,382.96 212,204.12 2,502,378.46 212,204.05 2,502,375.05 212,201.11 2,502,378.50 212,198.27 2,502,381 .'63 212,195.72 2,502,382.27 212,199.71 , 502,455.60 212,226.40 (Reserved for Compressors) G-14A 1825 G-19 1827 G-13 1831 G-15 1835 G-5 1838 1837 G-3 1833 G-2 1829 G-11 1825 G-lO 1829 G-17 & RD 1832 G-7 1832 1906 LEG #2: LAT = 60050' 23.313" LONG =151°36' 45. 982" 2,502,427.10 212,301.20 1880 37 38 39 40 41 42 43 44 45 46 47 4.8 2,502,421.45 2,502, 424.94 2.502,429.45 2,502 2,502 2,502 2.5O2 2,502 2,502 2,502 2,5O2 2,502 ,432.85' ,433.57 ,431.26 ,427.00 ,422.80 212,297.82 212,294.98 212,295.05 212,297.99 212,302.44 212,306.31 212,307.78 212,306.18 , 420.60 ............. 2'12,'302.25 ..... ,425.63 212,299.39 , 429.40 212,300.83 ,426.27 212,303.38 G-12, RD & 2 1874 G-31 1878 G-4 1882 G-1 1886 G-9 1886 G- 1 8 1884 G- 14 1880 .............. G.-30 ............. 1876 G-8 & RD 1B74 G-6 1879 G-32 1882 'G-16 1879 FEL 1409 1413 1415 1415 1412 1408 1404 1402 1'404 1408 1411 1409 1407 1486 1487 1491 1493 1491 1487 1483 1480 1480 1486 1483 1488 1484 1458 1383 " 1386 1 389 1389 1386 1382 1378 1376 ..... 1378 ...... 1382 1 385 1383 1381 STATE OF ALASKA ALA, ~A OIL AND GAS CONSERVATION COl,, ISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Datum elevation Union Oil Company of California (UNOCAL) 99' ~F or to K~L Feet 3'Addre~.O. BOX 190247, Anch, Ak., 99519-0247 6. Unit or PrO~d~eBay Unit 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate 1~ Pull tubing Alter Casing [] Other ~ 4. Location of well at surface 1879'N - 1381'W f/SE cor., Sec. 29, T9N R13W SM At top of productive interval 669'N - 1052'E f/SW cot., Sec. 27, T9N R13W SM At effective depth 432'N - 1327'E f/SW cor., Sec. 27, T9N R13W SM At total depth 317'N - 1462'E f/SW cor., Sec. 27, T9N R13W SM 7. Well number 8. Approval number 7-232 9. APl number 50-- 133-20162-00 10. Pool McArthur River FiE id 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Lengtl~76, Structural 601 ' Conductor .5,960' Surface 12,416' Intermediate 13,663' Production Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) 13,663 ' 10,129' feet Plugs (measured) feet 13,482 ' feet Junk (measured) 10,012' feet Siz,~,, Ce~e~tedurzven Measured d~, ~ue Vertic~¢~pth 17 3/4" 1850 sx 601' 601' 13 3/8" 2359 sx 5,960' 4,568' 9 5/8" 1000 SX 12,416' 9,249' 7" 1300 SX 13,663' 10,129' SEE ATI~ACHED 3 1/2", 9.2#, N-80 C~ 12,805' Packers and SSSV (type and measured depth) Baker perm. pkr ~ 12,048' and 12,750' 12. Stimulation or cement squeeze summary I~L%,LI V I_!~ Intervals treated (measured) See attached Treatment description including volumes used and final pressure JUL- 1 1987 Alaska 011 & Gas Cons, Commlssio, /tnnhnm.n~ 13. Prior to well operation Representative Daily Average Production or Injection Data OiI.Bbl Gas-Mcf Water-Bbl Casing Pressure Shut-in 5300 BWRD 1000 psig Average ~bing Pressure 2900 Subsequent to operation 14. Attachments Daily Report of Well Op~rationsZZ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed R(;/y Roberts Title Environmental Engineer Date06~29~87 Form 10-404 Rev. 12-1-85 Submit in Duplicate G-16 PERFORATION RECORD NEASURED DEPTH (OIL) TRUE VERTICAL. DEPTH PERF SIZE & NUMBER 12,120' - 12,145' 12,164' - i2,210' 12,275' - 12,315' 12,335' - 12,450' 12,520' -12,610' 12,685' - 12,725' 12,845' - 12,890' 13,i72' - 13,£70' 9057' - 9076' 9090' - 9124' 9173' - 9202' 9217' - 9300' 9350' - 9414' 9465' - 9491' 9571' - 9601' 9783' - 9846' Twelve - . 57" HPF I! I! !! I! Four - .46" HPF RECEIVED JUL- 1 ]987 Alaska Oil & Gas Cons. Commissio.~ Anchorage UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. ]' of 6 LEASE TBUS WELL NO. G-16 FIELD McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4-12-87 4-13-87 4-14-87 4-15-87 4-16-87 4-17-87 4-18-87 4-19-87 4-20-87 13,482' 12,800' Filled tubing and casing with FIW. Ran in hole with wireline and perfed tubing 12,671'-12,672', 5 spf to circulate. Circulated and killed well. Circulated well clean. Set plug in "X" nipple @ 336' and tubing plug at 290' Attempted to test tubing plugs but had communication to annulus~ Removed tree. Installed and function tested BOPE. Began building flowline and bell nipple. Completed flowline and bell nipple fabrication and rig up. Calibrated TOTCO unit. Pulled tubing plugs. Attempted to test BOPE. Hydril single gate leaked. Repaired gate and ran low pressure test (700 psi) on stack. Finished low pressure BOPE test. Pulled tubing hanger loose and 3-1/2", 9.2#, N-80 butt tubing parted with 70M9 over block weight. Pulled out of hole & recovered 1057.24' of fish. Top of fish at 1098.69'.. Set test plug and tested BOPE to 5000 psi. Picked up fishing tools. Engaged fish at 1111'. Pulled 5000# and tubing parted. Pulled out of hole. Recovered 844.29' of 3-1/2" tbg fish. Top of fish = 1955.29'. Ran in hole and tagged fish at 1955'. Latched fish and pulled out of hole. Recovered 1439.05' Top of fish = 3394.34. Ran in hole & tagged fish at 3394'. Latched'same and picked up 10,000# over. Tubing parted. Pulled out of hole and recovered 511.06'. Top of fish = 3905.40'. Ran in hole and tagged fish at 3905'. Latched same and picked up 50,000#. Riged up WL to cut tubing. Cutter wouldn't pass 1700'. Rig down WL. Pulled tubing to 103,000# over pickup and pulled seals out of packer. Circulated bottoms up. Circulated bottoms up and pulled out of hole. Recovered entire tubing fish of 8883.59'. Jacked up derrick legs to center crown over rotary. Picked up fishing tools and ran in hole picking up drillpipe. Ran in hole. Changed swivel packing. Tagged packer at 12,750'. Rilled over packer to 12,753' and packer fell down hole. Circulated bottoms up. Pulled out of hole. Ran in hole with spear. Tagged packer at 12,790', chased same to 13,091'. Landed 10,000# on packer with spear. Pulled out of hole. Pulled out of hole. No recovery (spear in released position). Redressed spear and ran in hole. Tagged packer with spear at 13,113'. Chased same to 13,350'. Landed 30,000# on packer with spear. Pulled out of hole. Recovered packer and entire tail assembly. Ran in hole with 6" bit and 7" casing scraper. Tagged fill at 13,360'. Cleaned out fill to ETD of 13,482 (retainer). Circulated hole clean (lots of scale in returns). Displaced hole with clean FIW. Finished displacing hole with FIW and shipped returns to production (twice). Pulled out of hole and laid down BHA #7. Rigged up Dia-Log and ran in hole to 13,300'. Logged casing profile to surface. Rigged down Dia-Log. Picked up R~TS and RBP in tandem, ran in hole and set RBP at 12,800' and RTTS at 12,774'. Rigged up Howco. Tested lines to 3000 psi, OK. Tested RBP to 2100 psi, bled to 900 psi in 4 minutes. No test. Released RTTS and RBP and circulated and worked pipe. Reset RBP at 12,800' and RTTS at 12,774'. Retested to 2100 psi, bled to 1000 psi in 3 minutes. No test. Released R~S and pulled to 12,693'. Mixed and pumped FIW and 21 sacks of sand. ~rk._ed_pi~pe~andwaited for sand to settle. I CEIE VD JUL - 1 1987 RlasKa Oil & Gas Cons. Commission Anchorage UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO, 2 of 6 LEASE TBUS .WELL NO,, G-16 FIELD McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4-21-87 4-22-87 4-23-87 4-24-87 4-25-87 RECEIVED JUL- 1 1987 Nask8 0ii & Gas Cons. Commissi~ Anchorage 12,802' 13,482 Finished waiting 1 hour for sand to settle. Ran in hole and tagged sand at 12,701'. Pulled up and set RTTS at 12,682'. Retested RBP to 2100 psi. No good. Pulled out of hole and laid down RTTS. Picked up RBP overshot tool. Ran in hole and tagged sand at 12,715'. Rigged up and reverse circulated sand out to 12,800'. Latched on to RBP and circulated. Unable to reverse out due to plugging action from scale particles. Circulated long way. Released RBP. Pulled out of hole and laid down RBP and overshot tool. Picked up EZ-drill retainer and ran in hole. Set retainer at 12,802'. Rigged up Howco and tested lines to 3000 psi, OK. Closed rams and tested 7" casing to 2100 psi, OK. Tested same to 3000 psi for 15 minutes, OK. Bled off and rigged up on 7" x 9-5/8" annulus. Pr~essured u~7" casing to 1000 psi a_nd7~_~ . 9-5/8" annulus to 2050 ps~, ~ad no ~o~uh~ca~i'0n or ~njec~. Ble~ ~ Rerouted production lfne in wellhead room #~"'~hat was against underside of 9-5/8" x 13-3/8" annulus valve of G-16 (the same valve repaired by "Boots & Coots") at 2400 hours. Finished fabricating and rerouting production line to free 9-5/8" x 13-3/8" annulus valve on G-16. Pulled out of hole and laid down cement retainer setting tool. Bled 9-5/8" x 13-3/8" annulus from 800 to 20 psi. Rigged up Howco to same and began pumping FIW. At 204 barrels pumped, had 4 BPM at 2050 psi, 5 BPM at 2125 psi at 216 barrels pumped. Bled to 1650 psi in 30 minutes and stabilized. Re-established injection and ran temperature log at 2400 hours. Finished temperature log while injecting at 3 BPM and 1850 psi, 567 barrels total pumped. Bled to 1700 psi and stabilized with pumps off. Rigged down loggers. Log revealed injection to 6060' (13-3/8" shoe at 5960'). Pressured 7" casing to 1500 psi, 9-5/8" x 7" annulus to 1700 psi and 9-5/8" x 13-3/8" annulus bled off. Rigged up Howco on 9-5/8" x 13-3/8" annulus, mixed and pumped 800 sacks of class "G" cement with .2% LWL, .4% Halad 344 and .25% CFR-2 with FIW (15.5 PPG slurry). Pumped initially at 2 BPM at 1800 psi, final at 1 B~ and 1200 psi. Did not bleed off. Cement in place at 0404 hours. Closed annulus valve. Waited on cement 12 hours, bled 7" x 9-5/8" from 595 psi to 0 psi quickly. 9-5/8" x 13-3/8" annulus from 100 to 0 psi. Shut-in both annuli. At 2030 hours, bled 7" x 9-5/8" from 550 psi to 0 psi quickly, 9-5/8" x 13-3/8" from 100 psi to 0 psi quickly. Shut in both annuli. Ran in hole with bit #2 and tagged retainer at 12,802'. Drilled up retainer. Ran in hole to 13,482'. Circulated bottoms up at 2400 hours. Finished circulating bottoms up. Pulled out of hole and laid down bit #2. Rigged up and made up 1150' of 4" and 4-5/8" Vann tubing conveyed guns plus Howco R~TS and test tools and LPRN valve on 3-1/2" drill pipe. Ran in hole and filled pipe to 4220' RKB. Tagged bottom at 13,482' with drill pipe measurement. Picked up guns to perforate. Rigged up Gearhart. Ran in hole with gamma ray tool to locate at R/A collar. GR tool failed. Pulled out of hole with wireline and changed out GR tool. Relocated collar at 2400 hours. Finished locating collar. NOTE: Vicky Lytle witnessed tie-in of perf guns. Pulled out of hole with GR and rigged down Gearhart. Rigged up fluid level. Set RTTS. Annulus dropped, fluid level in drill pipe rose. Howco by-pass opened filling drill pipe. Closed by-pass and released RTTS. Pulled out of hole to 4220' to clear drill pipe of fluid. Ran in hole and reset RTTS at 12,006' DIL. Rigged up fluid level. Closed VBR's and pressured annulus to 1250 psi noting LPRN valve opening. Pressure annulus to 2450 psi and fired guns. Fluid level rose at 1474 psi drawdown. Shot jarred interior shear circulating sub open and pressure bled off annulus within 1 minute shutting LPRN valve. Reverse circulated through choke. Released R~TS and continued to reverse circulate. Obtained shut-in and flow check. Well dead. Picked up and noticed 23,000# loss (weight of guns). Pulled out of hole and laid down Howco tools. Circulating - Flow sub sheared from outside in. lb guns. Waited on fishing tools. Fogged and snowed in at 2400 hours. UNION OIL CO. OF CALIFORNIA DRILLING RECORD 3o~ 6 PAGE NO, ~BUS LEASE DATE 4--26-87 4-27-87 4-28-87 4-29-87 4-30-87 5-1-87 E.T.D. 12,802' 12,797' 13,684' 12,790' WELL NO. G-16 FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Continued waiting on fishing tools due to fog and snow. Packed swivel. Tested BOPE as per test form to 3000 psi, annular to 1500 psi. Picked up and made up fishing assembly. Ran in hole, tagged and engaged fish at 13,311' and caught same. Pulled out of hole and recovered all of fish. Had 1 misfire out of 4000 shots. Laid down fishing tools and guns. Picked up bit ~2 RR 91 and 7" scraper. Ran in hole and rotated kelly at area of RBP setting depth at 2400 hours. Finished rotating at kelly and scraped 7" at area of RBP setting depth. Tagged fill at 13,459' (23'), cleaned out to 13,482'. Displaced hole with FIW. Pulled out of hole and laid down bit and scraper. Ran in hole with RBP & RT2S in tandem. Set RBP at 12,802' and tested to 2500 psi, OK. Set RTTS at 11,990' and tested backside to 2500 psi, OK. Held 1500 psi on backside. Ran in hole with Gearhart profile log to 3000'. Had damaged line. Pulled out of hole and stripped off wireline at 2400 hours. Pulled out of hole with Gearhart spinner survey tool. Rigged down wireline. Released Howco RT2S. Made arrangements for Dowell to bring aboard 16,000 gallons of 7.5% HCl blended with 0.29% J235, 0.49% ~5, 0.2% F75N, 0.1% J237 and 50#/1000 gallons L41. Supply boat with Dowell equipment arrived on location at 2100 hours. Offloaded and spotted acid tanks and pump skid. Rigged up to pump acid into "G" zone perfs at 2400 hours. Ran in hole with RTTS to 12,750'. Spotted 34 barrels of acid across "G" zone perfs. Pulled out of hole to 11,700' and set RTTS. Pumped 34 barrels of acid through perfs at a rate of 1.8 BPM at 3000 psi. Released RTTS. Ran in hole and set RTTS at 12,650'. Pumped and displaced 39 barrels of acid through perfs from 12,737'-12,697' (DPM) at initial rate of 1 BPM at 3100 psi and final rate of 1 BPM at 2900 psi. Retrieved RBP at 12,802'. Pulled up and reset RBP at 12,660' and set RTTS at 12,497'. 'Pumped and displaced 43 barrels of acid through perfs from 12,610'-12,520' (DPM) at an initial rate of 1/4 BPM at 3200 psi and final rate of 1.5 BPM at 1000 psi. Acid broke around RTTS at 43 barrels. Moved RTTS up hole to 12,255'. Continued operations with no circulation. Pumped a total of 239 barrels of acid through zones 3, 4 & 5 at a final rate of .7 BPM at 3000 psi. Released R~TS and RIH to retrieve RBP at 12,660'. Ran in hole to 12,797' and circulated bottoms up. Reset and tested RBP at 12,797' with 2500 psi. Pulled RT2S up to 11,990'. Waiting on Dowell to deliver mud acid to re-do "G" zone perfs at 2400 hours. Waited on delivery of 12-3 mud acid from Dowell. Cleaned and painted and made rig repairs from 0001-1600 hours. Pulled out of hole with RTTS and RBP at 2400 hours. Continued to pull out of hole with RBP and RTTS. Redressed tools. Cleaned and painted rig and equipment while waiting on acid delivery. Set trip tank in place on Rig #55. Beld off 7" x 9-5/8" annulus in 20 seconds, no fluid. Bled off 9-5/8" x 13-3/8" annulus in 8 minutes, no fluid. Left 7" x 9-5/8" annulus open. Closed and monitored 9-5/8" x 13-3/8" annulus. Built to 90 psi in 10 minutes. Continued building to 285 psi at 1100 hours. Ran in hole with RBP and RTTS. Set RBP at 12,790' and RTTS at 12,775'. Tested between tools to 2500 psi, OK. Pulled RTTS up to 11,990' and set same. Pressured backside to 1500 psi, OK. Pressured 7" x 9-5/8" annulus to 1700 psi. Bled off 9-5/8" x 13-3/8" annulus from 285 psi in 4 minutes. Rigged up tbwco to 9-5/8" x 13-3/8" annulus for injection rate test at 2400 hours. Pressured up on 9-5/8" x 13-3/8" annulus. Established no pump rate at 2000 psi. Pressure bled back and stabilized at 800 psi in 15 minutes. Bled pressure to zero. Hooked up 9-5/8" x 13-3/8" annulus to production %{ell clean tank. Shut in 7" x 9-5/8" annulus. Released UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO, 4 oE 6 LEASE ~US ,WELL NO. G-16 FIELD McArthur River Field DATE 5-3-87 5-4-87 5-5-87 RECEIVED JUL- 1 ]987 Naska 0il & Gas Cons, Cornmissic Anchorage E.T.D. 13,482' 12,746' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RT~S. Cleaned and painted. Supply boat arrived with Dowell crew and acid at 1030 hours. Rigged up to G-20. Pumped 10 barrels 7.5% HC1 in tubing for scale clean up. Mixed 850 barrels of 12-3 mud acid. Ran in hole with RTTS and set same at 12,250'. Opened bypass and broke circulation. Tested lines to 4000 psi at 2400 hours. With RBP at 12,790' and RTTS at 12,250' pumped first stage of acid job on "G" zones 3, 4, 5 & 6. Pumped 72 barrels of 5% HCl followed by 18 barrels of 12-3 mud acid at 3 BPM and 500 psi. Closed bypass. Continued pumping 12-3 mud acid at 2 BPM and 2900 psi. After pumping 244 barrels of 12-3 mud acid rate was 2 BPM at 2100 psi. Began adding 0.2% diverter at 275 barrels of 12-3 mud acid pumped, rate 2 BPM at 1000 psi. Decreased diverter to 0.1% at 0430 hours after pumping 389 barrels of 12-3 mud acid. Suction manifold on Dowell pump split at 1100 hours and shut well in. Changed out pump skid to B3-Titan at 1200 hours. Continued pumping at 2 PBM at 1000 psi. At 560 barrels of 12-3 mud acid pumped, stopped adding diverter. Finished 12-3 mud acid at 686 barrels pumped. Followed with 19 barrels of ammonium chloride water at 2 BPM and 1000 psi. Displaced acid with FIWat calculated displacement of 90 barrels.Rate 2 BPM at 1340 psi. Continued pumping and increased pressure to 3000 psi for a final rate of 4.3 BPM. Total FIW pumped was 120 barrels. Released RTTS at 12,250'. Ran in hole and retrieved R BP at 12,790' and pulled up hole. Set and tested RBP at 12,250' to 2500 psi, OK. Pulled up and set RSTS at 12,000'. With bypass open, pumped 22 barrels of 5% HC1 at 2.3 BPM and 150 psi. Followed with 66 barrels of 12-3 mud acid at 3 BPM and 150 psi. Closed bypass. Continued pumping 12-3 mud acid at 1 BPM and 3000 psi. After 155 barrels of 12-3 mud acid pumped, rate was 2 BPM at 600 psi. Pumped a total of 175 barrels of mud acid. Followed with 16.5 barrels of ammonium chloride water at 2 BPM and 400 psi. Displaced with FIW. Increased pressure to 3000 psi. Final rate 5.5 BPM at 3000 psi. Total FIW displaced was 140 barrels. Released R~TS and retrieved RBP at 12,250'. RIH to 12,800' and circulated bottoms up. Pulled out of hole with RTTS and RBP at 2400 hours. Continued to POH with RTTS and RBP. Down cup on RBP missing 1/3 of cup. Installed test plug. Tested pipe rams, kill and choke lines, choke manifold and upper and lower kelly cocks at 250 psi low and 3000 psi high. Tested hydril bag at 250 psi low and 1500 psi high. Removed test plug. Rigged up Gearhart. RIH with 6" gauge ring and junk basket to 13,220'. POH and recovered the missing rubber from the RBP. Made up Baker lower 7" D.B. permanent packer assembly with seal bore extension, crossover, one joint of 2-7/8" plastic coated tubing with seal lock connections, Otis 2-7/8" "X" nipple with seal lock connections and 5-3/4" OD wireline re-entry guide. RIH on wireline and set packer at 12,750' DIL/12,762' DP. POH with setting tool. Rigged down Gearhart. RIH with Baker test seal assembly on drill pipe and stabbed into packer at 12,762'. Closed hydril. Pumped 3.4 BPM at 1000 psi down 7" casing with no returns to surface. POH at 2400 hours. Bled pressure off of 9-5/8" x 13-3/8" annulus from 720 psi to 0 psi in 30 minutes. Produced 8.5 MCF during that time. Attempted to establish pump rate in the 9-5/8" x 13-3/8" annulus. After 11 barrels pumped, pressured up to 1000 psi and held with no bleed-off. Ran in hole with RBP and RTTS in tandem. Set RBP at 12,746' and tested to 3000 psi, OK. Set RTTS at 12,000' and tested backside to 1500 psi, OK. Performed a static and dynamic injection profile across the"G" zone perfs with temperature tool and R/A tracer. All injection was confined within the "G" zone. Perfs from 12,725'-12,685' taking fluid at 2320 BPD, 12,610'-12,520' taking fluid at 1080 BPD, 12,450'-12,335' taking fluid at 244 BPD, 12,315'-12,275' taking fluid at 1458 BPD, 12,210'-12,164' taking fluid at 269 BPD and 12,145'-12,120' taking fluid at 631 BPD. Finished logging at 2400 hours. /--.% UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO 5 of 6 LEASE ~'~US G-16 McArthur River Field WELL NO ~FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5-6-87 5-7-87 5-8-87 RECEIVED JUL- 1 1987 0il & Gas Cons. Commissior Anchorage 13,482 Continued water injection test into "G" Zone. Injected at 4.2 bpm with 2950 psi. Reran profile and temperature logs to reconfirm injection into "G" Zone. Pulled out of hole with RTTS. Retrieved RBP. Made up and ran in hole on 3-1/2" drill pipe with top packer assembly including seal assembly for bottom permanent packer and waterflood injection mandrel with dummy valve in side pocket. Tagged bottom packer at 12,750' DIL. Set top packer at 12,048' DIL. Pulled out of hole to pick up test seal assembly. Stabbed into bottom 7" permanent packer with seal assembly. Positioned string and set Baker 7" D.B. permanent packer from 12,060'-12,064' DPM. Dropped ball and set packer with 1000 psi. Pulled out of hole and made up Baker seal assembly on drill pipe. Ran in hole and stabbed into packer. Pressured up backside to 1500 psi, OK. Pulled out of hole. Redressed stab-in assembly. Ran in hole with 389 joints of 3-1/2" plastic coated tubing above top packer. Placed Otis "XA" sliding sleeve 1 joint above top packer. Tuboscope holiday inspected each joint in rotary table. Spaced out tubing and installed new stainless steel tubing hanger at 2400 hours. Spaced out tubing string and installed a new Cameron stainless steel tubing hanger. Changed well over to clean FIW with 0.5% Nalco 3900 Corrosion inhibitor. Landed tubing hanger and tested to 2000 psi, OK. Installed BPV in hanger and nippled down BOPE. Installed new injection tree and tested to 5000 psi, OK. Removed BPV. Turned well over to production. Released rig at 0700 hours 5-8-87. TUBING DETAIL BOTTOM PACKER ASSE~LY DESCRIPTION Otis WL re-entry guide 0.90 1 Jt - 2-7/8", 6.4#, N-80, IPC, Seal-lock tubing 27.91 2-7/8"Otis "X" Nipple 1.26 1 Jt - 2-7/8", 6.4#, N-80, IPC, Seal-lock tubSng 28.10 Seal bore ext. box + 2-7/8" Seal-lock pin X-O 0.50 Baker seal bore extension 9.40 Baker Model "DB" "7" Perm. Pkr 3.25" ID (Packer set on W.L. @ 12,750' DIL) 3.63 TOP PACKER ASSEMBLY LENGTH TOP BOTTOM 12,820.80 ' 12,821.70 12,792.89 12,820.80 12,791.63 12,792.89 12,763.53 12,791.63 12,763.03 12,763.53 12,753.63 12,763.03 12,750.00 12,753.63 Baker Mule Shoe Guide .58 Baker Seal Assembly 3.25" OD X 2.406" ID 8.67 Baker No-Go Locator (Locator is on btm pkr set at 12,750' DIL) 1.03 19 Jts - 2-7/8", 6.4#, N-80, IPC, Seal-lock tubing 525.44 2-7/8" Teledyne~erla Flow mandrel with Seal-lock and IPC 10.60 1 Jt - 2-7/8", 6.4#, N-80, IPC, Seal-lock tubing 27.37 3-1/2" box X 2-7/8" pin Seal-lock X-O 1.00 4 Jts - 3-1/2", 9.2~, ~7,80, IPC, Seal-lock tubing 121.01 2-7/8" box X 3-1/2" pin Seal-lock X-O 1.60 Seal bore ext. box X 2-7/8" Seal-lock pin X-O .60 Baker Seal bore extension 9.33 Baker Model "DB" "7" Perm. Pkr. 3.65 12,758.67 12,759.25 12,750.00 12,758.67 12,748.97 12,750.00 12,223.53 12,748.97 12,212.93 12,223.53 12,185.56 12,212.93 12,184.56 12,185.56 12,063.55 12,184.56 12,061.95 12,063.55 12,061.35 12,061.95 12,052.02 12,061.35 12,048.37 12.052.02 UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO 6 o£ 6 TBUS G-16 LEASE .WELL NO. FIELD McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 0217N/tjp TUBING DETAIL TOP PACKER ASSEMBLY (continued): DESCRIPTION Baker Mule Shoe Guide Baker Seal Assembly 3.25" OD x 2.406" ID Baker No-Go Locator (Locator is on top packer set at ~ 12,048' DIL) 1 Jt - 3-1/2", 9.29, N-80, plastic coated w/seal lock conns Otis 3-1/2" "XA" Sliding Sleeve 388 Jts - 3-1/2", 9.29, N-80, plastic coated w/seal lock conns 3-1/2", 9.2#, N-80, plastic coated pup joint w/seal lock conns 3-1/2", 9.2#, N-80, plastic coated pup joint w/seal lock conns 3-1/2", Seal lock x 3-1/2" butt plastic coated fig. nip Cameron stainless tubing hanger Landed below zero LENGTH TOP BOTTOM NOTE: There is 12' difference between drillpipe and DIL. There is 12.24' difference between tubing and drillpipe There is 24.24' difference between DIL and tubing. RECEIVED JUL- 1 ]987 -4tJasJ(tl Oil & (~as torts. Commission Anchorage .59 12,081.27 12,081.86 8.66 12,072.61 12,081.27 1.05 12,071.56 12,072.61 29.68 12,071.56 12,041.88 3.80 12,041.88 12,038.08 11,985.82 12,038.08 52.26 4.17 52.26 48.09 3.91 48.09 44.18 1.58 44.18 42.60 1.10 42.60 41.50 41.50 41.50 0.00 Alaska District Unocal Oil & Gas Dit ~'~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) 3une lO, 1987 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Blair, Unocal has recently completed the repair of two injection wells on the Grayling platform. The tubing was replaced in both wells G-16 and G-12 in order to prevent communication between the tubing and casing annulus. Following completion of the repairs, the tubing and casing annulus integrity was tested. The attached memo summarizes the results of those tests. Sincerely, S~~.~. ambert District Engineer SAL/nc/O395r Attachment cc: V.I. Lytle W.D. Kirchner - MOCO T. Wellman - ARCO RECEIVED JUN 1 1 1987 .&taska 0it & Gas Cons. Commission Anchorage Memorandum UNOCAL June 3, 1987 TO: FROM: RE' S. A. Lambert J. M. Quintan~ Casing Pressure~ for G-12 and G-16 The tubing /9 5/8" casing annulus has been pressurized and monitored on both G-16 and G-12. They have been filled with water and a pressure of 1500, psig maintained. A summary of the bleed off tests is as follows: ..~'/15/e~7--1) G-16 leaks 25 psi in a 24 hr. period (looses 1½ gal per day). Ko/(/07-' 2) G-12 has held 1500 psig for a 24 hr. period with no loss in pressure. These pressures will be maintained unless otherwise notified. CC' S. M. Wiese J. T. Beitia RECEIVED JUN 1 i 1987 Alaska 0ii & Gas Cons. Commission Anchorage FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. REI~E-IVE'D JUN 9 1987 · :..¢-~? .., r~'~"~ STATE OF ALASKA .'--~, /'Jr', ~ ALASi_ . OIL AND GAS CONSERVATION COMI~ ,SION ,4,-~..~. APPLICATION FO'R 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) Union 0il Company o¢ California (UNOCAL) 99' RT to HSL feet~, 3. Addrl~s.~0. Box 190247, Anch, Ak., 99519-0247 6. Unit or Pre~ze~[~i~ay Unit 4. Location of well at surface 1879'N - 1381'W f/SE cot., Sec. 29, T9N R13W SM At top of productive interval 669'N - 1052'E ¢/SW cot., Sec. 27, T9N R13W SM At effective depth 432'N - 1327'E f'/SW cot., Sec. 27, TgN R13W SM At total depth 317'N - 1462'E f/SW cot., Sec. 27, TgN R13W SM 7. Well number G-16 8. Permit number 68-109 9. APl number 50-- 133-20162-00 10. Pool McArthur River 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13,663' feet 10,129' feet 13,482' feet 10,012' feet Plugs(measured) Junk(measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 376 ' 26" Driven 601' 17 3/4" 1850 sx 5,960' 13 3/8" 2359 SX 12,416' 9 5/8" 1000 Sx 13,663 ' 7" 1300 sx measured true vertical Measured depth 376 ' 601 ' 5,960' 12,416 ' 13,663 ' 12,845 - 12,890'; 13,172 - 13,270' 9,563 - 9,597'; 9,804 - 9,868' Tubing (size, grade and measured depth) 3 1/2", 9.2#, N-80 $ 12,805' True Vertical depth 376 ' 601 ' 4,568' 9,249 ' l0,129 ' Packers and SSSV (type and measured depth) Baker FB-1 $ 12,750'; Otis "X" Nipple $ 336' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby.~,r~~ foregoing is true and correct to the best of my knowledge Signed~"~ "~'~'~l'ff3l~ I-(~De:['l:S Title Environmental Engineer Date 04/03/87 ~ Commission Use Only ' Conditions of approval Notify commission so representative may witness I .rova, No. ~ Plug integrity ~ BOP Test ~ Location clearancel ~t ?~;~:;.,?;~ ~ ~." ~.~'~ Commissioner the commission Date Approved by Form 10-403 'Rev 12-1-85 Submit in triplicate TBUS G-16 Procedure change: Unocal wishes to change procedure #8 of the approved Sundry notice to the following: #8. Reperforate Hemlock sands and perforate "G" Zone sands in one run using tubing conveyed guns. The invervals to be perforated are as follows: G-Zone Perfs: Depth Interval G-1 12,120 - 145 25 G-2 12~164 - 210 46 G-3 12,275 - 315 40 G-4 12~335 - 450 110 G-5 12 ~ 520 - 610 90 G-6 12,685 - 725 40 3-5i' Reperforate Hemlock Zone Hemlock Perfs: Depth Interval B-1 i2,845 - 890 45 B-4 13,172 - 270 98 143' With the exception of the above, the procedure on G-16 will remain as approved by the Commission on February 13, 1987, approval number 7-101. STATE OF ALASKA '~. ALASK.. OIL AND GAS CONSERVATION COMb,..,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) UNION OIL COMPANY OF CALIFORNIA 99' RT to MSL feet 3. Address 6. Unit or Property name P.O. Box 190247, Anchocage,~Ak. 99519~Q247 Trading Bay Unit Sec. 4. Location of well at surface 29, T9N, R13'W, SM. At top of productive interval 27, T9N R13W, SM. At effective depth 27, T9N, R13W, SM. At total depth 27, T9N, R13W, SM. 1879'N - 1381'W f/SE Cr., 669'N - 1052'E f/SW Cr., Sec 432'N - 1327'E f/SW Cr., Sec ~17'N - 1462'E f/SW Cr., Sec 7. Well number G-16 8. Permit number 68-109 9. APl number 50-- 133-20162-00 10. Pool McArthur River Field 11. Present well condition summary Total depth: measured true vertical 13,663 ' feet Plugs (measured) 10,129 ' feet Effective depth: measured true vertical Casing Length Structural 376 ' Conductor 601 ' Surface 5,960' Intermediate 12,416 ' Production 13,663 ' Liner Perforation depth: measured 13,482 ' feet Junk (measured) 10,012' feet Size Cemented 26" Dr iven 17-3/4" 1., 850SX 13-3/8" 2,359SX 9-5/8" 1,000SX 7" 1,300SX 12,845 - 12,890' true vertical 9,563 - 9,597'; Tubing (size, grade and measured depth) 3-1 / 2", ; 13,172 9,804 - 9.2#, Measureddepth ~ue ~rticaldepth 376' 376' 601' 601' 5,960' 4,568' 12,416' 9,249' 13,663' 10,129' RECEIVED - 13,270' 9,868' N-80 FEB 1 3 1987 Alaska 0il & Gas Cons. C0mmj @ 12,805 ' Anchorage Packers and SSSV (type and measured depth) Baker'FB-1 @12,750; Otis "X" Nipple @ 336' 12.Attachments Description summary of proposal Qf Detailed operations program [] BOP sketchX~ , 13. Estimated date for commencing operation 3-1-87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and ~,qr~pr3it to the best of my knowledge Signed /~/~/~ ~l~_-_Title Environmental Engineer RoyJ Roberts C(~mmission Use Only Date Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. ? I ? [] Plug integrity [] BOP Test [] Locat. i,o, nc~earance ~%~f-O-~'~ ',--..-, , ........ · F ',: .... :¢~;, by order of "'t:~ Commissioner the commissio'n Dat~/J Submit in triplicate TBUS G-16 PROCEDURE: 1. Rig up over TBUS G-16, leg 2, slot 48. 2. Kill well, observing 9-5/8" X 7" annulus and 13-3/8" X 9-5/8" annulus. 3. Remove tree, installad test BOPE. cannot set BPV due to hanger threads corroded away. (Set tubing plugs if possible.) 4. Pull and lay down 3-1/2" tubing. Tubing tail at 12,805'. Tubing must be speared to retrieve due to hanger threads are no longer intact. 5. Mill over and recover Baker Model FB-1 production packer set at 12,750'. Correct 13-3/8" X 9-5/8" annulus pressure as follows: Test casing to 2500 psi. If casing tests, attempt to pump down 13-3/8" X 9-5/8" annulus establishing rate below shoe fracture pressure. If rate can be established and fluid flow determined, attempt to pump cement down annulus from surface to shoe. If' casing does not test, locate hole in casing. If hole is below 13-3/8" shoe, squeeze as required. If hole is above 13-3/8" shoe, attempt to circulate cement down casing and up 13-3/8" X 9-5/8" annulus to surface. 6. Clean out and test squeezes and casing again if needed. 7. Run casing inspection log from TD to surface. 8. Reperforate Hemlock sands and perf "G" Zone sands in one run using tubing conveyed guns (12,120'-12,170', 12,260'-12,420', 12,530'-12,580', 12,595'-12,630', 12,675'-12,710' , 12,845'-12,890', 12,904'-12,985' , 13,005'-13,088' , 13,108'-13,142' , 13,172'-13,270' ) 9. Acidize "G" zone with '15% HC1 if required. 10. Run single 3-1/2" completion string utilizing flow regulators for "G" Zone and Hemlock injection. 11. Remove BOPE, install and test tree. 12. Put well on injection. DAS:gr 0339D FEB 1 3 1987 Aiaska Oil & Gas Cons. Anchorage 1 VALV~ . o . r' CHOKE I MANIFOLD G'~-E TO MUD PUMPE, & CEMENT UNIT , ,-- ~---~- ) ANGLED FILL UP LINE ~ ~.~~./:'.'.'2 HYDRIL , . PiPE RAMs' PIPE RAMS ![~..~.~q!.L-. ._.II~.,~AtlA~y.~Aj KILL LINE '"' ~'~ "- I I "- ~- ~'~--'~FRoM MuD PUMPS · ~~ ...... & CEMENT UNIT OPERA TOR FURNISHED' WELL NAME: RIG CONTRACTOR; RIG: STACK PRESSURE RATI~.JG: CHOKE LINE SIZE & MSP: . -- NOTE, ALL "' ' ~ ~ ''*~""' HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT NOTES: i. HYDRAULIC VALVES OPEN AUTOMATICALLY WHEN DIVERTER IS CLOSED. FLEX HOSE ~//) 18 TO BE USED IF NECESSARY WiTH DD$' ... APPROVAL,' RECEIVED FEB 1 ~ 1987 DEPT. APPROVAL . Ill f . I Ill II ' I .- I. · I - ----'* 13 5/8" BOPE STACK 5M OR 1OM Alaska Oil & Gas Cons. Commission Anchorage ' _. ., i ,,. · _ --- --ii c~^w, B H___L c~<c), ,C $1~ALF.. NO NE , ALL WORKOVER OPERATIONS ..-. '-UNi'bN OIL"'CO~PANY" OF CAkiFORNIA /' ~'""~P' ' ~ ' ...... '~1 1_ 7: 29 8~E~':'~"~4 ~ #~:~c OF · . 'l Ill I" ~ STATE OF ALASKA --~-'~ ALASA~ ilL AND GAS CONSERVATION ~,~,,VlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 68-109 3. Address 8. APl Number 909 W. 9TH AVE., P. O. BOX 6247, ANCHORAGE, AK 99502 50- '133-20162 4. Location of Well Cond. #48' Leg #2, 1879' N & 3381 W from SE corner, Sec 29. T9N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) .99' RT to MSL J 6. Lease Desianation and Serial No. ADL-18730 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number TBUS G-16 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations IX] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were reperforated in 1/81:. 12845' - 12890' Bench 1 13172' - 13270' Bench 4 JUN - 1 Jl~2 A!aska Oil & Gas Cons. C01nm 14. I hereb~y c~ f~reg.~oing is true and correct to the best of my knowledge. Signed ~ ,~ Title District Engineer ..... 3~;-H.. base /ne space oelow Tar L. ommlsslon use Date May 24, 1982 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10-7;3 Sul)ml t "1 ntentlons" 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.) Oil F~l GAS I-II WELLW~' WELL'' OTHER 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR P.O. Box 6247 Anchorage, A'K 99502 4. LOCATION OF WELL At surface Cond. #48:' Leg. #2, 1879' N & 1381 W .from SE corner, Sec 29- T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT to MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20162 6. LEASE DESIGNATION AND SERIAL NO. APL ] 8730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME tradin9 Bay Unit. 9. WELL NO. TBUS G-16 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 27' T9N, R13W, S.M. 12. PERMIT NO. 68-109 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L-- PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS ,Other) Reperforate existing intervals SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTEI Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent {letalls, and give pertinent dates, Including estimated date of starting any proposed work. It is propsoed to reperforate the following intervals' 12845 - 12890 Bench 1 13172 - 13270 Bench 4 Subsequent Work Reported on Form No. J ECEIyEo JAIV£ £ 1981 Ala,II(a Oil & Gas Cons. anchorai$ Commission 16. I hereby~~u* and correct S,GNED ,This space for State Of..~.~C/se,. APPROVED BY [;~~ TITLE CONDITIONS OF APPROVAL, IF Ah~ BY ORDER O~ THE COf~3MISSION T,TLE District enqineer DATE 1/20/~1 ~OMMI$$I O NEi~ See Instructions On Reverse Side DATE /'- Z ~-8 ! ' ~pproved Returned Form No. P-4 RE¥. ~- 1-70 ,,,,% STA-I: OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1o O,L [] CAS r-1 water injector WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL SUSMIT IN DUPLICATE ~ ~, ' C ,F ~'-.!G 6. LEASE DESIGNATION AND S~RIAL NO. - 7. IF .NDIAN'ALOTTEE OR TRIB, NA~. ' C~?('L 8. UNIT FARM OR LEASE NAME .... ~ '~ G~C r I ..... ~ REV Trading Bay Unit ..... ,~¢~.,~ 9. WELL NO. TBUS 6-16 (14-Z7-~~-. 10. FIBLD AND POOL, OR WlLEAI' '"'¢"~ -. 11. SEC. T. R. M. (BOTTOM HOLE OBIE~iVE) Section ·27' 19~, R13~, S.~. 12. PERMIT 68-109 Conductor 48, Leg 2, 1879'N & 1381'W from SE corner. Section 29, T9N, R13W, S.M. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PEI~FORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 4/1/78 13,663'TD 13,154'ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,663' Ran new 7" RTTS pkr on 3 1/2" DP & set @12,500'. Tested BOPE & lines to 3000 psi - o.k. Tested 3 1/2" x 7" annulus to 3000 psi - o.k. Set pkr & tested annulus to 3000 psi @12,600', 12,692', & 12,784' - o.k. Set pkr @12,815' & pressured annulus to 3000 psi - bled to 2600 psi in 4 min w/ returns out DP. Moved pkr to 12,692' & pressured annulus w/ returns out DP. Pooh w/ DP. Ran 6" bit & 3 - 4 3/4" DC on 3 1/2" DP. 4/2/78 13,663'TD 13,154'ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,663' Drilled out cmt ret @12,828' in 2 hrs. Pushed ret to ETD @13,482' and circ hole clean. Pooh. Ran 5 3/4" gage ring on W.L. to 13,200'. Ran 7" Howco cmt ret on W.L. & set @13,154'. Ran 7" Howco RTTS on 3 1/2" DP and set @12,692'. Pressured 3 1/2" x 7" annulus to 3000 psi - bled to 2600 psi in 2 min w/ returns out DP. Moved pkr to 12,600' and repeated test w/ same results. Moved pkr to 11,677' and repeated test w/ same results. Pooh and checked each tool jt w/ Martin-Decker torque gage on rotary tongs. RECEIVED HAY 1 b Division of Oil & Gas 6ons=a, ati:,l 14. SiGNEO(~.~lheteby/~-Ctt~fyt~,thefjl~reg¢~isttueandr~brtect_.. ~/~/~/~. /~/~/t/~ TITLE Dist. Drlg. Supt. DATE 5/15/78 ,¢ tlllll R. i.~1 i~.llCl~[r,/ ./ NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be fi/ed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. 4/3/78 4/4/78 4/5/78 13,663'TD 12,596' ETD (cmt plug) 9 5/8" csg @12,416' 7" csg @13,663' 13,663'TD 13,154'ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,663' 13,663'TD 13,482 ' ETD (RET JUNK) 9 5/8" csg @12,416' 7" csg @13,663' Finished pooh w/ 3 1/2" DP checking make-up torque on each tool it. Ran 7" RTTS pkr on 3 1/2" DP and set @1855'. Pressured 3 1/2" x 7" annulus to 3000 psi and bled to 2600 psi in 2 min. Pooh w/ RTTS. Ran 7" Baker full-bore tension pkr on 3 1/2" DP and set @480'.. Pressure annulus-same results. Isolated test system and tested BOPE to 3000 psi - o.k. Pooh w/ pkr and laid new squeeze line from squeeze manifold. Ran 7" RTTS pkr on 3 1/2" DP and set @188o5~ Tested annulus and squeeze lines to 3000 psi - o.k.,,.~ w/ pkr and set @12,781'. Pressure annulus to 3000 psi & bled to 1650 psi in 3 min. Moved pkr to 12~596' and tested annulus to 3000 psi - o.k. ~s~i helleak 12,596' 01~@12 CFM & 1600 psi. PI @18 - ~ 2~ psi after 4 min w/ pump off. Squeezed csg leak w/ 300 sx C1 "G" cmt w/ .75% D-31, .3% D-19, .1% D-6 & 5% sand mixed @122 #/CF to lock- up'@ 6000 psi w/ 37 CF of cmt in DP (488 of 525 CF displacement pumped). Pressure bled to 5000 psi in 40 rain and held. Released pkr and rev. out 40 CF cmt. CIP @6:00 p.m. Pulled pkr to 11,655' and pressure csg to 2000 psi w/ pkr hanging for 2 hrs. Released pressure and pooh. Finished pooh w/ squeeze pkr. Ran 6" bit & three 4 3/4" DC on 3 1/2" DP to 12,000' and WOC total of 12 hrs. Drlg out hard cmt from 12,544' (ll CF backflow after squeeze) to cmt ret @13,154' in 12 hrs. Circ hole clean and pooh. Ran 7" Howco RTTS pkr on 3 1/2" DP and set @1856' Tested squeeze & 7" csg from 1856'-13,154' to 3600 psi w/ FI~ for 45 min - o.k. Released pkr after testing squeeze and pooh. Ran 6" bit & three 4 3/4" DC on 3 1/2" DP and drlg up cmt ret @13,154'. Pushed ret to 13,482' and circ hole clean. Pulled up to 13,000' and closed BOPE. Established injection rate w/ FIW into Hemlock Bench 4 perfs 13,172' - 13,270' down 3 1/2" x 7" annulus @6.9 DFM or 1770 BPD. Pooh w/ bit. Ran 7" Howco RTTS pkr on 3 1/2" DP and set pkr @13,158' (Note: pkr will not take wt. and hold in interval fr. om 13,152'-13,157' - 3 pkrs set & drilled up in this interval). Offloaded acid & RU to acidize Hemlock Bench 4, 4/6/78 13,663 'TD 13,482' ETD (ret junk) 9 5/8" csg @12,416' 7" csg @13,663' Finished offloading acid and RU w/ Halliburton to acidize. With 7" pkr set @13,158' between Hemlock Benches 3 & 4, acidized Hemlock Bench 4 perfs 13,172'-13,270' down 3 1/2" DP w/ 4000 gal 15% HC1 followed by 10,000 gal 12% HCL + 6% HF as follows: Pumped acid to perfs (96 bbl FIW) 1.2 BPM & 3000 psi Pumped 3230 gal 15% HCL into perfs 1.2 - 1.8 BPM & 3000 psi Acid broke around blank between 2.9 BPM & 2700 psi Bench 3 & 4 13,142'-13,172' C1 osed BOPE PI annulus w/ FIW 1.1 BPM & 2400 psi PI DP w/ 12-6 acid 1.2 BPM & 2100 psi Inc rate for remaining acid PI annulus w/. FIW 2.8 BPM & 2900 psi PI DP w/ 12-6 acid 2.5 BPM & 2700 psi Displaced acid to perfs and overflushed w/ 100 bbl FIW @2.5 BPM & 2300 psi. DP press bled to 600 psi in 3 min & annulus press bled to 1600 psi and held. Moved pkr to 12,562' and RU Howco cementer to DP. Pumped 250 bbl ?IW @4.5 BPM & 3400 psi (6480 BPD rate @max platform inj press of 3400 psi). RU Go Int. W.L. and RIW / profile tools. Tools malfunctioned @ beginning of survey. Pooh and repaired tools. 10 4/7/78 13,663'TD 12,750'ETD (perm pkr) 9 5/8" csg @12,416' 7" csg @13,663' Finished repairing Go Int. W.L. injection profile tools on third attempt and RIH w/ W.L. Placed well on platform injection system @5836 B1)D @3300 psi down on 3 1/2" DP & below 7" retrievable pkr set @12,562'. Ran W.L. radioacti've tracer survey:'indicating +3500 BP being injected into Hemlock Bench 4 perfs 13,1--72'-13,270' w/ remaining +2300 BPD being injected above Bench 4. Ran 5 15/16" gage rin-g & junk catcher on W.L. to 12,820'. Ran perm pkr w/ tail on W.L. and could not work below '1692'. Pooh & RD W.L. 11 4/8/78 13,663 'TD 12,750' ETD (perm Pkr) 9 5/8" csg @12,416' 7" csg @13,663' Ran 7" Baker Model FB-1 perm pkr w/ 6' millout ext, 15' seal bore ext, 1 jt 3 1/2" butt tbg, & 3 1/2" Otis "XN" nipple on 3 1/2" DP and set pkr @12,750' w/ "XN" nipple @12,803'. Pooh w/ DP. Ran Baker Model G locator seal assy w/ 20' seals on 421 its (1.2,712') 3 1/2" 9.2# N-80 butt tbg w/ ABC modified coupling and hydrotested each jt to 4000 psi. 12 4/9/78 13,663'TD 12,750' ETD (perm pkr) 9 5/8" csg @12,416' 7'.' csg @13,663' Spaced oUt tbg in Baker perm pkr @12,750' and tested pkr to 1000 psi. Pulled out of pkr and displaced 7" x 3 1/2" annulus w/ 500 bbls Nalco Visco 938, 1153 & 3656 pkr fluid mixed in FIW according to specifications. 'Landed tbg in perm pkr w/ end of tb~ @12,770', top of Model G seal assy @12,748', 3 1/2" Otis "XA" sleeve @12,719' and 3 1/2" Otis X nipple @337'. Installed BPV and ND BOPE. NU 4" 5000 psi double master individual valve X-mas tree and tested to UOCO specs. Modified injection line and___p~l_ac_~d on i?DJ_e~JJ2n @6:30 p.m. w/ stab rate of 6432 BPD & 3~-~~00 mia. Released rig from TBUS G-16 @12:00 mid .4/9/78,: Form 10-403 REV. 1-10~'~ Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate 5. APl NUMERICAL CODE 50-133-20162 6. LEASE DESIGNATION AND SEFIIAg NO. ADL 18730 7. IF INDIAN, ALLOTTEE OR TRlllE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit f ! 9. WELL NO. TBUS G-16 (14-27) 10. FIELD AND POOL, OR WILDCAT McArthur River-Hemlo~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Oo not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) O,L I--! GAS I---I WELLI.iJ WELLL.-J OTHER water injector 2. NAME OF OPERATOR Union 0il Co. of Calif. 3. ADDRESS OF OPERATOR P. 0. Box 6247, Anchorage, AK 99501 ? 4. LOCATION OF WELL ~- At surface Conductor 48, Leg 2, 1879'N & 1381'W from SE corner, Section 29, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT to MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27, T9N, R13W, S.M. 12. PERMIT NO, 68-109 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING L.~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF.' WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly ~tate all Pertinent (lltllll, and give pertinent dates, Including estimated date of starting any proposed work. Workover operations began on March 29, 1978. The BOPE was NU and tested. The 3 1/2" injection tbg. was pulled. A hole was located in the 7" liner between 12,596' and 13,154' with test packers. The hole was squeezed with 300 sx. cmt. through an RTTS pkr. set @12,596', with a cmt. ret. set @13,154', above Bench #4 perfs. The cmt. was drilled out to the ret. and the squeeze was tested to 3600 psi. The cmt. ret. was drilled up. Hemlock B~enCh #4 perfs 13,172'-13,270' were acidized with 4000 gal. 15% HC1 and 10,000 gal 12-6 mud acid. The acid was followed with 1000 bbl. FIW. A 7" perm. pkr. was set @12,750'. The 3 1/2" injection tbg. was hydro-tested to 4000 psi and RIH.. The annulus was displaced with pkr. fluid and the well returned to injection. Work was completed on April 19, 1978. The present injection rate is 6432 BWPD. 16. I hereby ce~/iif~y hat the foreg'pir~'~ true and correct ECEIVE APR 2 ] 1978 Division of Oil and Gas Anohoritl 4/14/78 // ? d IIII i~. [.,cl. I Ib~llUl~[' (This sl~e'for State office use) Dist. Drlg. Supt. DATE APPROVED BY CONDITIONS OF APPROVAL, IF ANy: TITLE , DATE See Instructions On Reverse Side Union Oil and Gas D~¥ision: Western Region Union Oil Company .;alifornia P.O. Box 6247, Anchorage, Alaska 99502 .... Telephone: (907) 276-7600 union April 13, 1978 Mr. O. K. Gil'breth Division of. Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Gilbreth- Enclosed is the following forms for your information' TBUS G-17, GRAYLING PLATFORM Subsequent Sundry Notices and Reports on Wells Well Completion Report TBUS K-23, KING SALMON PLATFORM Sundry Notice and Reports on Wells Monthly Report TBUS D-15, DOLLY VARDEN PLATFORM Monthly Report TBUS D-7, DOLLY VARDEN PLATFORM Monthly Report - "YL tING PLATFORM Si ncerely yours, ~'--~l.i__m_.R~) Call ende'r D~-~'. Drlg. Supt. RECEIVED API:t 1 4 1978 ¢~1 0;l and Gas C;.,~i~r~rYa~. Form No. P-4 REV. 3- 1-70 A SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER RECEIVED 2. NAME OF OPERATOR Union Oil Co. of Calif. APR 1 4 1978 3. ADDRESS OF OPERATOR P. 0. Box 6247, AnchOrage, AK 99501]ivision 4, ~, " c::,s Cons~rvat 4. LOCATION OF WELL Grayling Platform, Conductor 40, Le9 2, i886'N & 1386'W of SE corner of Section 29, TgN, RI3W, S.M. 5. AP1 NUMERICAL CODE 50-'i33-20037 6. LEASE DESIGNATION AND SERIAL NO. ADL 18730 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unit ~n TBUS G-1G 10. FIELD AND POOL, OR WILDCAT HcArthur Ri ver 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 28, TgN, R13W, S.M. 12. PERMIT NO. 67-47 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES 1N HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS J.UNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 3/29/78 13,663'TD 13,152'ETD (perm pkr) 9 5/8" csg @12,416' 7" csg @13,663' Commenced rig operations @12:01 a.m. 3/29/78. Moved Rig 54 over conductor 48 in leg 2 and RU. Loaded 3 1/2" tbg and 3 1/2" x 7" annulus w/ F1W and tbg went on vacuum. Installed BPV and removed 4 1/2" 5000# CIW double valve single block X-mas tree. Installed and tested to Union specs 12" 3000 psi BOPE. Pulled 3 1/2" tbg out of perm pkr @13,152' w/ 128,000# hook load and circ. hole w/ FIW. Pooh and LD total of 429 its 3 1/2" tbg. Found 1" hole @ top of pin end threads on jt #421 (approx 12,890'). Ran 6" od Tri-State flat bottom pkr mill and three 4 3/4" DC on 3 1/2" DP. 3/30/78 13,663'TD 13,482' ETD (junk pkr) 9 5/8" csg @12,416' 7" csg @13,663' Finished RIH w/ 6" pkr mill on 258 its 3 1/2" 13.30# Gr E & 160 its 3 1/2" 13.30# S-135 DP to perm pkr @13,152'. Milled up pkr in 1 1/2 hrs and pushed junk to ETD @13,482' (prior pkr & ret junk). Circ hole clean and pooh w/ DP. RU Go Int. and ran 5 3/4" od gage ring and junk catcher on W.L. to 13,000'. 3/31/78 13,663'TD 13,154'ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,663' Finished running 5 3/4" gage ring on Go Int. W.L. to 13,000' & pooh. Ran 7" Baker cmt ret on W.L. and set @12,828'. Ran 7" Baker retrievamatic on 3 1/2"'DP to 12,500' and unable to set pkr. Closed BOPE and PI 3 1/2" x 7" annulus @24 CFM & 2200 psi. Pooh and LD pkr. Ran 7" Howco RTTS pkr on 3 1/2" DP & set @12,500' Tested 3 1/2" x 7" annulus to 3000 psi - o.k. RIH w/ pkr a~d tagged cmt ret @12,828'. Pulled up to 12,818' and set pkr. Attempted to test cmt ret @ 12,828' & PI @14 CFM & 2400 psi w/ partial return out annulus. Attempted to release pkr & backed off 3 1/2" DP. Screwed back in and pooh checking torque on each tool it. Dist. Drlg. Supt. 4/13/7A // .11 m ~ F~ I ! ,',r-,t-i'"'~- DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Union Oil and Gas/'%~sion' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600' December 6, 1977 Hr. O. K. GilbreCh Division of 0il & Gas 3001 Porcupine Drive Anc~prage, AK 9950~ RE ~US G-9, GRAYL~ATFORM Dear Mr. Gilb.reth' Enclosed for your approval are three (3) copies each of Sundry Notices for the above captioned projects. Si ncerel'y yours, Ji'm" R. Cal 1 ender Dist. Drlg. Supt. ,, sm · RECEIVED 't 1971 Diviu!etl of 0it & ~',~ ¢,~rm~rvati0n Form~l 0.403 REV. 1-10-.73 Subml t "1 ntentlons" 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.) l. OIL l--1 GAS F--1 water injector WELLL~J WELL L.-J OTHER 2. NAME OF OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchoraqe~ AK 99502 4, LOCATION OF WELL At surface Conductor 48, Leg 2, 1879'N & 1381'W from SE corner. Section 29' T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT to MSL -14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-! 33-?0! 62 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradina Bav 9. WELL NO. TBUS G-16 (14-27~ 10. FIELD AND POOL, OR WfLDCAT McArthur River-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27: T9N, R13W, S.M. 12. PERMIT NO. 68-109 3orr, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING L.~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well ComlHetion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent ~let&lls, and give pertinent dates, including estimated date of starting any proposed work. Originally TBUS G-16 was completed as a Hemlock producer of Benches 1-4. In 1974, this well was converted to an injector. At that time, Benches 1-3 were squeezed off and Bench 4 was fracture stimulated for injection. A sharp increase in injection from 3000 BWPD to 5000 BWPD occurred in July, 1976. An injection profile shows that this increase is due to a casing leak at +12,700' which causes water to be injected into the G-6 sands. - It is proposed to squeeze off the casing leak and acid stimulate Bench 4. Attached are a detailed plan of procedure and a wellbore schematic. ,6. I hereby certl~?hat the fo~o~h~ue~d correct /Ylim Ri £~ll~nd~r- (This spa~e"~or State office use) Dist. Drlg. Supt. =ATE . 12/2/77 TITLE De ~;roleum F.n§ineer See Instructions On Reverse Side 12-2 7' 77 DATE Approved Cop~ Returned PLAN OF PROCEDURE: 1. MoVe rig over Conductor #48 in Leg Room #2. 2. Load hole wi th FIW. 3. Install & test BOPE. 4. Pull injection tbg.. Set 7" cmt. ret. @12,800'. 5. Locate hole in 7" csg. & sqz. with Class "G" cmt. · . 6. Drill out cmt. & test sqz. 7. Burn over & pick cmt. ret~ @12,800'. 8. Set test pkr. @12,800'. 9. Run injection profile survey. 10. Acidize Hemlock Bench #4 perfs, if required. ll. Re-run injection equipment & return to injection. OPERATING TIME: Workover START DATE: COMPLETION DATE: 18 days April 17, 1978 May 4, 1978 Z N~ Ar+ I,~ t?~v~r ?~e I~ C=~ay l,'n.9 Pla+~or~ -. -o cm~'d w/I8~O ~ (,171' "l " O V Y'~ol 9-5'~" 40, z..3,~,47~ N-So ~-//o Z 12.700' o~.q [e~k ~n ? L /7..800' Satyr Pl~d~l F p~rzn pkr I~TH SCALE 1293' [. I I1~ III ii. ! I I I II I I I III ...... . ' ' ~ Ill II i IIII I I 5712' $ I I I II IIII ~ II I ! , ) 7419' 1 12,0~. DEPTH- SOUTH- EAST - Fo f'.'n 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports, in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELLI I OTHER SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "/APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR UNION OIL C@4PANY OF CAJ. IFORNIA 3. ADDRF-SS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL Atsurface Conductor #48, Leg #2, 1879'N & 1381'W from the St:. corner. Section 29: T9N, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99'RT to MSL. 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO; TEST WATER SHUT-OFF L-~ PULL OR ALTER CASING L.--J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) 5. APl NUMERICAL CODE 50-133-20162 6. LEASE DESIGNATION AND SERIAL NO. ADL-18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-16 (14-27) 10. FIELD AND POOL, OR WILDCAT HcArthur River-I!emlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27: TgN, R13W, S. M. )ort, or Otl~r~)ata .t. '1 /4 WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) *See Below ABANDONMENT* H (NOTE.. Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ].5. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. *To squeeze off Hemlock Benches #1, #2 & #3, fracture treat Hemlock Bench #4 & convert to a ttemlock Bench #4 Injector. -- ..... 2. 3. 4. 5. 6. 7, 8. 9. 10. 11. 12. 13. 14. 15. Rig up over well. Open "XO" sleeve @ 12,637'& killed well w/64# filtered Inlet wtr. Removed x-mas tree. Installed & tested. BOPE. Released Baker tlyd. pkr. @ 12,733'. Pulled &'laid dwn. 3 1/2" 'tbg. & accessories. CO 7':' csg. to 13,087'ETD. Set cmt. ret. on WL @ 12,798,. Squeezed off Hemlock Benches #1 & #2 w/ 400 sx. of cmt. Drlg. out cmt. ret. @ 12,798.' & 13,098' & cmt. between ret. CO 7" cs~. to 12,462'. Ran CBL-GR Collar Log from 13,400' to 12,600'. Reperf. Hemlock Bench #4 from 13,172' to 1'3,174' w/ 3 1/2" csg. gun. Set cmt. ret. on WL @ 13,155'. Tested Bench #4 for zone isolaii0n between Bench #3. I-Iad communication. Set ret. @ 13,095,". Squeezed perfs from 13,108~ to 13,1,42' w/ 150. sx. cmt. Drlg. out ret. @ 13,095' ~ cmt. to 13,150~. Tested perfs, to 2500 psi-ok. Drlg. out ret. @ 13,155' Pushed to 13,462'. Set RTTS @ 13,158' & tested Bench //4 to 4250 psi w/ no communication around Bench #3. CO 7" csg. to 13,400' ® Reperf. Hemlock Bench #4 fr,om 13,17.2' to 13,240' w/ 4. cs~. gun. ~ ~o. P~ STATE Or' ~m a~J,,a ~V. ~- 1-70 OIL AND GAS CONSERVATION COMMrri'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT o,~. [-] o,,a j-] o,., Injector WELL WELL NA.M-~- OF OPI!IRATOR UNION OIL COMPANY OF CALIFORNIA ADDRESS OF O~ATOa 909 West 9th Avenue, Anchorage, Alaska 99501 4 LOCATION OF WELL Section 29: TgN, R13W, S. M. ~ API NUNIERICAL ~ODE 50-133-20162 LEASE DESIGNATION AND SE'IRIAL NO. ADL- 18730 IF INDIA)~. ALOTTEE O~ TRIBE NAME 8. L~IT FAI%M OR LEASE NAME Trading Bay Unit 9 WELL N'O State G-16 (14-27) 10 FIF/2~ AND POOL. OR WILDCAT ~-'~'lcArthur River-Hemlock action 27: TgN, R13W, S. M. , Il. P~IT NO 1~. R~ORT TOTAL D~ AT ~D OF MON~, C~NG~ IN HO~j~: ~,~,~2~NG JOBS INCLUDING S~T ~ VOL~ US~. P~O~TIO~S. ~TS ~ ~SgLTS ~SH~~~ ~ HO~ A~D SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~~ ~ HO~ ~ITIONS ;~s-~ .... Note: Refer to Monthly Report of Drlg. & wa Operations for TBUS G-16 dated 7/8/74. Commenced operations on TBUS G-16 @ 12:01 pm, 7/16/74. Rigged up & killed well. Removed x-mas tree. Installed & tested BOPE to UOCO specs. Pulled & laid dwn. 3 1/2" tbg. ~ accessories. Made bit ~ scraper trip to 13,400'. RIH w/ RTTS & RBP. Straddled Bench #4 parrs from 13,172' to 13,270'. Pumped into perfs @ 4 cu. ft./min. w/ 4500 psi. No communications around blank from 13,142' to 13,172'. Tested squeezed parrs in Benches #1, #2 & #3 to 2500 psi-ok. Pooh. RU Schlumberger & reperf, btm. 70' of Hemlock Bench #4 from 13,270' to 13,200' w/ 4" cst. gun @ 4 hpf. Rill w/ RTTS [ set @ 13,157'. Acidized Bench #4 w/ 4000 gallons 12-3 mud acid & 800 gallons E-95 solvent. Fracture treated Bench #4 parrs from 13,172' to 13,270' as follows: VOL[gdE SAND CONCE~rRATION RATE PRESS. 168 bbls. -0- 1I. 5 bbl~/~in.. 800-0-' 'p'si 119 bbls. 1/2#/gal. 10 bbls/min. 8400 psi 119 bbls. l#/gal. 9 bbls/min. 8500 psi 89 bbls. 1 1/2#/gal. 9 bbls/min. 8500 psi 7 bbls. 1 1/2#/gal. .5 bbls/min. 8900 psi (Sanded out) Released RTTS & rev. out sand. Pooh. RIH w/ 6" bit & 7" csg. scraper. CO sand fill from 13,191' to 13,462'. Pooh. RIH w/ RTTS & set @ 13,1S8' Established stabilized inje_ction~ rat~_oF ~820 BW~..D~ into Bench #4 using ~latform injection system. Pooh. Made bit& scraper trip. Ran & set Baker Model "F" perm. pkr. @ 13,1S2'. Ran 3 1/2" tbg.-hydrotested to 6000 psi. Stabbed into perm. pkr. Spaced out & landed tbg. Installed BPV. Removed BOPE. Installed & tested x-mas tree to SO00 psi-ok. RELEASED RIG @ .1.2..:.00 NOON, 7/25/74 for Deactivati_on. 14. I hereby e SmN~ -,--~s--,, ~ -:,.~,.----,~----- District Drl~. S~t. n.~ 8/10/~4, NOTE--Report on this fo~ is required for each calsndar ~th~ regardless of the status of operations, end must ~ flied in duplicate with the oil and gas conaervatbn commiffee by the 15~ of the suec~ding mon~, ~le~ Othsrwise d~rected. · Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports,' in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12, PERMIT NO, 3oft, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. TBUS G- 16 (cont...) 16. 17. 18. 19. 20. Injected wtr. into Bench #4 @ 150 BWPD w/ 3500 psi. Completed well. Tbg. & annulus press, equalized while injecting into }lemlock Bench #4. Pulled tbg. Reperf. Hemlock Bench #4 from 13,.279'.. to 13,200' w/ 4" csg. gun. Fracture treated Hemlock Bench #4. 'Established injection rate of 1820 B~,~D w/ 3450 psi. Completed well as a Hemlock Bench #4 Injector. 16. I hereby cer~y that the forego~[ng is true and correct //.li-m R. ~al lender - (This space'or State office use) Dist. Drlg, Supt, DATE 8/10/74. APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' T IT LE DATE See Instructions On Reverse Side Form No. P--~ R~'V, 3- I-?0 STATE O1'-ALASKA SUBMIT IN DUPLICAT~ OIL AND GAS CONSERVATION COMMI'Fi'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. °"" r'-t ~, NAM.~- OF OPERATOR Injector UNION OIL COb{PANY OF CALIFORNIA 3. ~DbRESS OF OPkRATOR 909 West 9th Avenue, Anchora_~e: Alaska '4. LOCATION OF W~ 99501 Conductor #48, Leg 2, 1879'N & 1581'W from the SE corner. Section-29: TgN, R1SW, S. M. API NUiVIEPdCA~ ~ODE 50-135-20162 LEASE DESIGNATION AND SEI~IAL NO. ADL- 18750 ? IF INDIA~, AL~DTTIgE OR TRIBE NAME 8. L,~IT F~%IVl OR LEASE N~ME Trading Bay Unit 9 WEI~ NO State G-16 (14-27) 10 FL!~ A_~qD POOL. OR WILDCAT Nk~rthur River - Hemlock I! SEC, T.. R.. 1%3. (BO'I~I'OM HOI~ Section 27' TgN, R15W~ S. M. 12. P]~LNIIT NO 68-109 13. REPORT TOTAL DEPTH AT END OF MONTH, CHkNGES IN HOLE SIZE. CASING AND C~%IENTING JOBS INCLUDING DEPTH SET ~ VOLUlVI~ USE~, PF-~ORATIONS. ~FF. STS ~ RESULTS FISPI/NG JOB8 JLq~K ~ HOI~E AND SIDE-/q~CKED HOLE AND A_NY OTHER SIGNIFICANT CI~A-~GES IN HOL~ C~OI~DITIONS Commencedoperations.on well G-16 for conversion to a Hemlock Bench #4 Injector @ 12:01 am, 6/10/74. Rigged up & killed well. Removed X-mas tree. Installed & tested BOPE to UOC0 specs. Pulled & laid dwn. 5 1/2" tbg. & accessories. RIHw/ 6" bit & 7" csg. scraper to 15,087'ETD. Ran 7" gauge ring & junk basket to 15,087,. Ran & set cmt. ret. @ 12,798'. Squeezed off Hemlock Benches #1 & #2 w/ 400 sx. Class "G" cant. to a final press, of 5000 psi. RIHw/ 6" bit & drlg. out ret. @ 12,798', firm cmt. opposite Benches #1 & #2 perfs.& ret. @ 15,087' C0well to 15,462'. Ran CBL-GR Log from 15,400' to 12,600'. Perf. Hemlock Be~ch #4 from 15,172' to 13,174'. Ran & set cmt. ret. @ 13,155'. Stabbed into ret. w/ 5 1/2" DP. }{ad conmlunication between Bench #5 & #4. Spotted 6 sx. of sand on top of ret. @ 13,155'. Pooh. Ran & set cmt. ret. @ 13,095'. Squeezed off Hemlock Bench #$ w/ 150 sx. of Class "G" cmt. RIHw/ 6" bit. Drlg. out ret. @ 15,095' ~ firm cmt. opposite Bench #5 perfs. Tested perfs to 2500 psi - ok. Washed sand off top cf ret. @ 15,155'. Pooh w/ 6" bit. RIH & stabbed into ret. @ 13,155' w/ 5 1/2" DP. Attempted to test Hemlock Bench #4 w/0 success due to seals leaking on ret. RIHw/ 6" bit & drlg. ret. @ 15,155'. Pushed ret. to 15,462'. RI}lw/ 7" RTrS tool & set. @ 13,158'. Press. DP to 4250 psi w/ no communication between Bench #5 & Bench #4. Released RTTS & Pooh. RIHw/ 4" csg. gun ~ perf. Hemlock Bench #4 from 15,172' to 15,270' @ 4 hpf. RIHw/ 6" bit & 7" csg. scraper to 15,400'. Rigged up ~ ran 5 1/2" tbg. w/ hyd. pkr. Spaced out ~ set hyd. pkr. @ 15,156'. Removed BOPE. Installed ~ tested x-mas tree to 5000 psi. Released rig @ 12: 00 pm, 6/21/74. While injecting into G-16, tbg. & annulus press, equalized. of G-14, the tbg. will be pulled in G-16 for repairs. Following completion ,IIIL 6 'i974 ..DIVISION OF OIL AND {]AS mom~v-~-.~~'~r'.~/~F~l~'~l~ Dist. Drlv. S~t ............ ~A~ 7/8/74. NOTE--Re~ort on this form is required for .~ch calendar ~nth~ regardless of the ~tatus of operation, and must ~ flied in duplicate with the ' oil and gas conservatbn commi~ee bythe IS~ of the suec~ding mn~, ~le~ otherwise directed. Union Oil and Gas Di~"'~. n: Western Region Union Oil Company o, California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 unl, n June 4, 1974 Mr. Homer Burrell Division of Oil ~ Gas State of Alaska 3001 Porcupine Dr. Anchorage, Alaska 99S04 Dear Mr. Burrell: RE: TBUS G-l§ (14-27) FORM'10,403 ' ' --- ~ _~ : : llllj Enclosed for your approval are three (3) copies of the Sundry Notice ~ Reports on Wells for Trading Bay Unit State Well #G-16, Grayling Platform. sk Enclosures (3) Very truly yours, Jim R. Callender District Drlg. Supt. JUN 5 i974 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.) 5. APl NUMERICAL CODE 50-133-20162 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. ~VL%L~ GAS r'-] OTHERWELL 2. NAME OF OPERATOR UNION OIL COHPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 i ' 4. LOCATION OF WELL Atsurface Conductor 48, Leg 2, 1879'N 5 1381'W from SE corner. Section 29: TgN, R13W, S. lq. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT to HSL. Check Appropriate Box To Indicate Nature of Notice, Rei 14. 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-16 (14-27) 10. FIELD AND POOL, OR WILDCAT i HcArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27: T9N, R13W, S. Fi. 12, PERMIT NO. 68-109 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) See Below PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. *To squeeze off Hemlock Benches #1, #2 ~ #3, fracture treat Hemlock Bench #4 and convert to a Hemlock Bench #4 Injector. 1. Rig up over well. r.3 iii?'4 2. Open "XO" sleeve @ 12,700' ~ kill well w/68# salt water. 3. Remove x-mas tree. Install ~ test BOPE. ~t~),!:iN ~;"', (Iii, Ai'i0 (I~,,~ ' ,t tN '"","~, ' "' 4, Release Baker Hydraulic pkr, @ 12~733~, Pull 6 la¥ dwn, 3 1/2" tbg. ~8.~;acce~sories, 5, CO ~" csg, to 13~087~ETD, 6. Set cmt. retainer on WL @ +12,800'. Squeeze off Hemlock Benches #1 ~ #2 w/ +400 sx. of cmt. - ~ - 7. Drlg. out cmt. retainer @ 12,800' ~ 1~,098'.~ cmt. between retainers. CO 7" csg. to +13,400'. ~un CBL-GR Collar Lo~ from 13,400' to 12,600'. Reperforate Hemlock Bench #4 from 1~,172' to 13,174' w/ 3 1/2" csE. gun. Set cmt. retainer on WL @ +13,150'. Test Bench #4 for zone isolation between Bench #3 to 1 psi/ft. Eradient. -Squeeze for zone isolation if necessary. e 9. 10. Form 10-403 REV. 1-10~73 · Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL i i OTHER 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. )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 ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. PlAN OF PROCEDURI~: (cont...) 11. 12. 13. 14. CO 7" csg. to +15,400'. RePerfoamte He~lock Bench #4 from 15,172' to 15,240' w/ 5 1/2" csg. gun. Fracture treat Hemlock Bench #4. Complete well as a Hemlock Bench #4 Injector. ESTIMATED OPERATING TIME: Sixteen (16) Days. SIG ~- ~ JLa R. Call n' TITLE · ~ District Drlg. Supt. DATE 5/29/74 (This space for State office u~) / CONDITIONS OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side Approved Copy .. .Union Oil Company~'~,California June 18, 1973 TO W}DM IT I~RY CONCERN: Due to a mix-up inmailing lists and inconsistency in forms, all repair records and drilling well records since'February 21, 1972 arc being redone and distributed. You will be receiving copies that you may or may not have already received soon. Please replace those on file with the new records. JRC/sk Enclosures District Drilling Supt. '".~,~-.' ,.F ,OIL AND GAS Form P--3 P. EV. 9-30-6 9 Sabrnit "Intentions" in Trtplieat~ & "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 de~pen Use "APP-LICATION 'FOR ~'EHi~iT-2~' '~or such 'p~o~osal.~) WELL WELL OTHER 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501. 4.LOCATION OF WELL At ~-,ace Conductor 48, Leg 2, 1879 'N and 1381 'W from SE Section 29' TgN, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 99' RT to MSL. Check Appropriate Box To I,ndic~te Niat'ure of NOtice, Re ~. AP1 NI.I1VI.EI~C~ CODE $0-!33-20162 6. LEASE DESIGNATION A.ND SERIAL NO, ADL- 18750 ?. IF IN-DIA2~, AJ-,LOTTEE OR TRIBE NA3VIE 8. umw, ~A~ OR L~.ASE ~i~. 9. ~L NO. atate a-16 (14-271 10. F~ ~D POOL, O~ WI~C~T M~rg~ur River - tIemlock 11. SEC., T., R., M., (BOSOM O~E~IVE) Section 27' T9N, R13W, S. M. 12. PEI~MIT ~O. 68-109 ~ort, or Other D~ta NOTICE OF INTENTION TO TEST WATER 8HUT-OFF SHOOT OR ACIDIZE REPAIR WELL CHANOE PLAN]~ ' EURSEOUENT REPORT OF: MULTIPLE COMPLETE FRACTURE TREATMEN, T ~ ALTERING CASING ABANDONS SHOOTINO OR ACIDIZING ABANDONMENT* __ (Other)sqz bottom water chan~e ~as asses. ~Other) (NOTE: Report results of multiple compl~ion '~n Well Co . repletion or Reeompletion Report and Log form.) I5. DERCRIB£ PROPOSED OR COMPLETED OPERATION8 (Clearly state all pertinent details, and atve pertinent dates, ineludin~ estimated date of starting any proposed work. 1. Moved rig over well G-16. Killed well w/ 68# inverraul. 2. Re~ved tree, installed and tested BOP's. 5. Pulled tubing, cleaned out to 15,200' w/ bit and scraper. 4. Squeezed off bottom water. Cemented retainer at 15,098,. Top of cement at 15,087' 5. Cleaned out to 15,087' ~/ bit and scraper. 6: Re-ran 5 1/2" buttress ~tubing w/ Baker 5 1/2" x 7" t~d. Packer at 12,750' and 11 Otis gas lift mandrels 'in~e string. 7. Displaced invermul in annulus w/ diesel oil. Installed ball valve. 8. Placed well on production. Prig was released at 8/31/72 16. I hereby ~hat the for~g~in~ true and correct (This space for State office use) APPROVED BY CONDITION~ OF APPROVAL, IF ANY: TITLR D,, ,.e,." r~: '1:' C~L AND GA5 D*T~ Novamh~.r 3, 1972 DATE See I, nstructions On Reverse Side ~m No. ~,---4 STATE OF ALASKA SUBMIT IN DUPLICATE REV. ~- I-?0 OIL AND GAS CONSERVATION COMMI'rI'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS API NU~IEPACAL CODE 59-133-20162 LEASE DESIGI~ATION AND SERIAL NO, ADL- 18730 1. '? IF INDIA~, ALOTTEE OR TRIBE NAME O,~ ~] G,, [---] W,LL WZL~ OTHZ, 2. NAME OF OPERATOR Union 0il Company of California ,, 3. ADDRESS OF OPERATOR 909 W. 9th Avenue. Anchnrn~e. A1 ~qkn OqqN 1 4. LOCATION OF W~ ~' ' Conductor 48, Leg 2, 1879'N and 1381'W from the S.E. corner. Section 29: T9N, R13W, S.M. 8. L,~IT FAR~ OR LEASE NAME Tradi n~ g WELL State G- 16 (14- 27 10 FI.E~D A_ND POOL. OH WILDCAT _ M~~r River-~loc~ n SEC, T., R.,M. (~OMHO~ o~ ~ction 27: Tgn, ~SW, S.M. 12. PERMIT NO. , 68- lO9 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA. NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PERFOlq_ATIONS. TESTS ANT) RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TH~CKED HOLE AND AiVY OTHER SIGNIFICANT C-'H. ANGES IN HOLE CONDITIONS Comnenced operations on TBUS well #G-16 at 12:00 n_~o.n, 8/25/72. Operations from 9/1/72 to the completion ~f ~'-i6 are as follows: Opened "X0" at 12,654'. Displaced invermul w/diesel 'in annulus and tubing. Closed sleeve. Tubing tested - ok, to 2500#. Rigged down Otis. Released rig for .move to G-9. Produced well for rate and clean up prior to acid stimulation at later date. Rig released at 8:00 pm on 9/25/72. OCT 1 7 197 DIVISION OF OIL AND GAO ANCrHO2AC~~ 10/14/?'2 SIGNED NOTE--Report on this form is required to, each calendar month% regardless 0~-t~ ;ta~u$ ~t ~)~),ration~ and mu, t ~ tiled 'In duplicate with t~le oil and gas ¢onservat/on committee bythe 15th of the succeeding month, u~le~ otherwise directed. ~L - 18730 ia. TYPE OF WELL~~: f- '~:~! : i I I I - WELL ~ WELL - V~J~~ Other ~ ~ ~ ~ 7. IF INDI~, ~O'I"I~E OR TRIBE N~ ~. ~:,~ o~ co.,L~o~: Relocate gas v~s ~ ~ _ ~7o W~:LL ~ ov~ ~ ~x ~ n.~CK ~ ngSVR. ~ ~fffer 2. NAME OF 0PERATOn DIViSlO~ O~ OIL AND Union 0il Co~y of Califo~ia 3. ADDRESS 0F OPERATOB 909 West 9th Avenue, ~dlorage, Alaska 99501 4. LOCATION 0F WELL '-(R~O~ ~OC~{O~ C~M~r~M ~ {~ ~CCord~O~ ~{~ ~ ~ r~q~{r~MJ~)* ~,.u~. Conductor 48. Leg 2, 1879' N & 1381' W from S. E. co,- er. ~ction 29: TgN, R13W, S. M At top prod. interval reported below 1553' S ~ 7480' E of surface location. At total dep~ 2043' S ~ 7893' E of surface location, l~. ~zT ~o. 68-109 8/25/72 I 9/25/72 . ! 9/25/72 I 9~, RT ~hn,,, M~T. .60' RT tn MST. 99' 18. TOTAL DE~H ~ & TvD~9.'PLUG, B~CK MD & ~D~. ~ ~LT~LE CO~L., [ 21. - .... INTERVALS DRILLED BY ' HOW~Y' ROTARY TOOLS ' ' CABLE TOOLS ~. PRODUCING !N~VAL(S), OF ~IS COM~TIO~--TOP, BOSOM, N~E (~ AND ~)* 123. WAS DIRE~ONAL ~ SURVEY MADE Hemlock 12844 '~ 9547'~ i ~270 'ND Q87~'%~ i Yes 24. Thee E~CTEIC AND OTH~ LOGS RUN DIL, ~, BHC, ~NIC' LL3, ~ GR-CBL. CAS~G RE.RD (Report all strings set in well) 17-3/4" I .3!2 wall / spir~weld '6011 22" ] 7SO sx None ,,5/8" ~7~,43.5~,49~ PllOI_ M-gO :11416 12-1/~" ~nnn ~ LINE~ ~CO~ l'"~ .... ~UBING RECOP~ S~Z~ TOP (MD) None 3 1/g" 12803 i 12733 · i i 12844-12884 13108-13142 Set bridge p,~g' at 13 ~098' 13005-1308812904-12985 13172-132~0. 20sx of cemeJ~ on plu~. / 80. P~ODUCTIO~ DATE FIRST PI%ODUC~ON [~ODUCT10:NMEII{O~ (Fl°wit]g'gaslif~'purnp~g-sizeandtypeOfpump)Gas Lift ~V(EL[~TATUS (Producingorsnu .... ) mroducin¢ DATZ OF T~ST, ~OURS TEST~ '[CI¢OXE SiZE [PROD'N FO,~ OI~BDL. G~MCF. WATE~BBL. [ GAS-OIL __~/10/72 12~ i 124 r~? 658 152.5 FLO~', ~I~IHG' CAS~G P~ESSU~g [CALC~T~ OI~BB~. GAlaXY. ~ss' 125 980 ]~<'H°u~ [ 1316 I 305 31. pmvosmuoN oF gxs (8otd3 u,e~ Ior l~el, ve~t~d, etc.)' 8. UNIT,FA/iM OR LE~kSE NAME TradSn~ Bay Unit 9. Wlm'.L NO. State G-16 (14-27) 10. FIELD AND POOL, OR WILDCAT lqcArthur River - · tiemlock 11.SEC., T,, R., M., (BOTTOM HOLE OBJECTIVE) Section 27' TgN, RI3W, S. H. I 24,5 WATER--BBL. [OIL GRAVITY-AP1 (COP~.) I49 I S2.0 I TEST ~VITNESS~D BY 32. LIST 01C ATTACHMENTS 33. I hereby? e{r~¥ that the foregoing and attached information is complete and correct as determined from all-available records sm~:~ _~'~¥<' ~L~A~~r/~L~, Drilg. Supt. vi~ g/2.9/72 ....... --~/.T~ m 1:] C.~ 1 J ,=ri,a,:,-,,- ' ' - *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct welJ completion report and log on all types of lands and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items '~0, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and i~ item 22 show the prcJuc~r~g intcrv<~l, or intervals, top(s), bottom(s) and name (s) (if any) for only the intervc~l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce. J, show- ing the additional data pertinent to such interval. Item's6: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). ' ~4. SUMMA. ItY OF ~ORIVIATION TF~'I'S INCLUI)IN(i 'iN'I'~'~V~'L TESTED, pH,E,,2~.~UIIE DATA A.ND~bVIERIE.~ OF OII-, WATEII AND MUD NAM~ ; I : I' a~. CORE DATA~' A'I'I'ACll I1RIE~' D~I~mO~s O~; LITtIOLOGY. POnOSITY~ FI{A~R~. A~:-nm~n~l) s.ows OF Om. o~ on . GEOL ~ No. P-4 STATE G, AULSKA .sumcrr ~ tr~,UCA~ ' OIL AND GAS CONSERVATION CO~I~EE . c0_,33_20162 J , , ,~ · , , ,,,, , ,~ ~ -~'~-'~ '~ "~ MONTHLY REPORT. OF DRILLIN~ ~ ~.t =~:o..mo~ .x~ ~zs~-~o _~ AND WORKOVER OPERATIONS .- ~L - 18750 I 4 ENO ...... I 5 FN~ W~LL _ W~LL , I 9 Gr:QI I I Union Oil Con~y of Califo~ia Trading Bay Unit, -ri .... 3 GEOL RFV ADD~S O~' O'~~ " ' ' ~ WZ~ ~O ''/ I 909 West 9~ Avenue, ~cho~age, AZ~ka 9950Z State G-Z6 (Z4 _.~, .~.~- CONFER~ ~nductor 48, Leg 2, 1879'N and 1381'~V from S.E co~er McAr~ur River -~,~u~k ~ction 29- T9N, RI3W, ~i. ,~ S~.o~ r.. ~.. ~¢. (~o~o~-.~. ~ .. Section 27: T9N, ~3W, ~I 1~. P~IT NO .... 68-$09 . 13.REPORT TOTAL DEiPTH AT F..~D OF MONTH. CHA_\'GF_~ IN HOLE SIZE. CASING A~ C~NG JOBS INCLUDING D~ SET A~ VOLL~ US~. P~O~TIO~S. ~TS ~ ~SULTS FISHING JO~ JL~K L~ HO~ ~ND SIDE-~CKED HOLE ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIOHS Con~nenced operations on TBUS well #G-16 at 12:00 noon, 8/25/72.. Attempted to open sleeve at 12,700' above packe~, pdrfora-ted 't'ub-lng at 12,708'. Changed over to invermul. Installed BPV and removed x-mas tree. Installed BOP' s. Unseated packer. CirCUlated botton~ up. Pulled 3 1/2" tubing, packer and accessories. RI}I w/6" bit and 7" scraper to 13,200'.. Circulated and conditioned invermul to 68#/ cu. ft.. POOH. Rigged up wireline unit and set }iowco EZ cement retainer at 13,098'. Unable to break dcm~t below retainer with 2500 psi - held pressure for 30 minutes - ok. Spotted 20 sacks of cement ("b" w/ 1% D31), on Howco 2Z drill retainer at 13,100' pulled to 13,080 w/ 3 1/2" DP and reversed out excess cement. 'WOC. RIH w/ bit and scraper. Found hard cement at 13,087' P01-{. Ran and landed 411 its 3 1/2" NS0 buttress tubing with I~A/d packer at 121730', and 11 gas lift valves i~ place. Set packer and tested same with 3000 psi - ok. Installed BPV. Removed BOE. Installed Christmas tree. Tested tree with 4000 psi - ok. Opened 'Q(0" at 12i634'. P00H w/ wire line. hereby the~re j a~i ~orrect ' ' s,~m~.Y(_ k~(,u/_w.__C~C~r~' Dist. Drilg. ~pt .,~ 9/14/72 ~ --Repot) on this form ts required for ~ calendar ~thi regardles3 of tho ltot~ of operations, and must N filed in duplicate with the all and gas conGervotion commi.ee byfhe 15~ of the su~c~ding ~n~,~le~ Otherwise directed. · ~; .~ ' R~V. 9.~0-~9 1. Submit "Intentions" in 'Trtplioate & "Subsequent Reports" in Duplicmte 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 Us~ "APPLICATION 'FOR ~'EP, I~iT-~' 'for such 'pi~o~mosal~') . . . WELL WELl, OTI~ER 2. NAME OF OPERATOR Union 0il, Company of California 3. ADDRESS OF OPERATOR 909 W. 9th Ave., Anchorage, Alaska 99501 4. LOCATION OF WELL At surface Conductor 48, Leg 2, 1879'N ~ 1381'W from SE corner Section 29, T9N, R13W, ~. 13. ELEVATIONS (Show whether DF, RT, GR. etc. 99' RT above MSL ~. APl NLrM~RICAL CODE 50-153-20162 6. L~-~ASI~-"D~GNATION A-ND SE~I*~ N ~ 187~0 I I aC-/ S~ate G-16 (14-~7) lo. ~ ~ ~, o~ w~ca~ FILE, N~r~ur ~ver - He~lock Zon~ "~- , , , , 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 27, TgN, R13W, SVl. 12. PERMIT I~TO. 68-109 Check Appropriate Box To I,ndicate N~t'ure of N~tice, Re: ~ort, or Other Dat~ ' NOTICI~ OF INT[NTION TO: TEST WATER SHUT-OFF ~--~ PULL OR ALTER CASINO ~-~ FRACTURE TREAT MULTIPLi~ COMPLETE SHOOT OR ACIDIZ~ ABA~DO~e REPAIR W~LL CHANO~ PLANS I SUBSMQUmNT RIBPORT 01[': W,T.R SHUT-Or' ~ R,PAIRINO WI~LL I--' FRACTL'RB TREATM B'NT I__I ALTERING CASINO [ ] 8H00TIN0 OR ACIDIZIN0 ~ ABANDONMENT' {% f(7~,, f_Rebor}~result&..$f multiple completion on Well Com~letion or Reeompletion Report and ~o{ form.) 15. DKSCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, aud~lre .~.ertlnent ,d.ates, including estimated date of startius an)' proposed work. ~ i,; ' ''~' '* ~ ' ~N FOR ~D~ ~PAIR otvi~,~ o? <:.~, ,. ~,~ ~,~ ~is well is cu~ently pr~ucing 657/438 wi~ ~3.3~ cut ~d 2363 GLR. It's P.I. has declined, but ~ ~itude is ~certain du~ to lack of pressure ~ta. ~e well did flow up to 2500 ~PD on initial co~letion. A recent production log on G-16 indicated water entry to 'be from benches 3 and 4 ~rith only 257 BOPD. There are numerous up structure locations to recover any oil that is shut off. The well is equipped with 10 gas lift valves with the bottom valve positioned at 10,923'. Because of the change in bottom hole pressure and fluid gradient, the present downhole gas lift assembly is not operating at maximum efficiency. It is proposed to kill the well with Invermul, pull tbg, plugg off bottom water entry from benches 3 and 4, change gas lift ~alves and mandrels. It is also proposed to acid stimulate the intervals-above benches 3 and 4 to increase productivity. A 1S00 BOPD pro~ductipn increase is anticipated following acid stimulation, Squeezing off water entry and change in gas lift assembly. . . . Continued Form P--3 ~ "~ ~ ~ Submit "Intentions" in Triplicate ~.. --lfl~V. 9-30-69 '(' '~ & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION: COMMrI-fEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FoR PER~V~iT-L~' '/or such 'p~;o~osal~j J. WELL WELL 5. APl NUiVIERICAL CODE 's." L~s~. D~S~GNAT~ON ~ND SW. mAh NO. 7. IF INDIA.N, ALLO'IwI~E OR TRIBE NA2VLE OTHER 2. NAME OF OPERATOR 8. UNIT, FAH~ OR LEASE NAME 3. ADDRESS OF OPEI~ATOR 9. WE~L NO. 10. FIELD A~D POOL, OR WII~DCAT TBUS G-16 (cont.) 4. LOCATION OF WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc. 14. Check Appropriate Box To I,nd~cate Niat'ure of NOtice, Re 11. SEC., T., .R., M., (BOTTOM Heine OBJECTIVE) 12. PERMIT NO. ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER BHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIRWELL MULTIPLE COMPI.ETE ABANDONs CHAN0, PLAN, Other) EUBeEQUENT REPORT OF: I REPAIRINO WELL FRACTURE TREATMENT ~l ALTERING CAI~INO -i sIHOOTING OR ACIDIZINO ABANDONMENT® (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. PROCEDURE: . 2. 5. 4. 5. 6. 7. 8. 5 10. 11. 12. 13. 14. Move rig over G-16. Kill well w/68-70#/cu.ft, invemul. Remove xmas tree. Install ~ test BOF.. Pull tbg. CO to 13,250'+- w/7" csg scraper. Set 7" cmt retainer at 13,100' -on wrl, to isolate wtr entry from benches 5 and 4. Ont thru retainer allowing mt to come back in on top of retainer. PO w/o reversing. WOC 18 hrs. CO (when cmt fi'm) to 15,088'. Reperforate 2 hpf any portion Of Perforated zones found to be covered w/mt on CO run. Rerun sa~e tbg w/additional 3-1/2" tbg tail at 15,070'+-, with additional and respaced gas lift mandrels (w/o valVes) and rebuilt Baker pkr. Remove BOB. Install ~ test xmas tree. Disp Invermul w/diesel oil. Set wrl plug in tail of tbg. Set ~ test pkr. Run gas lift valves in diesel. Put well on production via gas lift until cleaned up. Acid stimulate well through tbg as per the attached procedure by Dowell. Acidize in stages, w/25,000 gal 12-10 mud acid and 20,000 gal 2.5% }EL. Place well back on gas!lift and produce spent acid off £ormagion. a$~ soon as possible. ~",' '.. : · :~ ~ 3/20/72 Estimated Starting Date: 10/26/71 16. I hereby certLf~ ti/t ~he~lr~,otq~ iS true ,nd correct "' .m..D I~'~-. ~~~ ,X,L~ Dist. Drlg. S~t. CONDITIONS oF iPPROFAL, ~ A~: See I, nstructlons On Reverse Side D&TE Approved Copy Returned 1/r Foi~ P--3 ~ Sulm~it "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE Of: ALASKA OIL AND GAS CONSERVATION; CO,MMITI'E~ SUNDRY NOTICES AND REPORTS ON WEI, I~ (Do not use this form for propos, als to drill or to. deepen or plug back to a dif£ierent reservoir. Use "APPLICATION FOR P~IT--" for such proposals.) · 2. NAMEOFOPERATOR Union 0il Company of California 3. ADDtLESSOFOPERATOR 507 W. Northern Lights Blvd., Anchorage, Ak. 99503 4. LOCA. TION. O,F WELL Atsurface Conductor 48, Leg 2, 1879'N & 1381'W from corner Section 29, T9N, R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 99' RT above MSL ~ &ppmpri~te Box To l, ndica*e N~ature of N~o~¢e, Re, NOTICE OF INTENTION T0: TEST WATER 8HUT-0FF ~--] PULL OR ALTER CASING ?. IF INDIA.~, ALLO~ OR TRI'I~E ~ 8. UNIT, FAI~VI OR LEASE NA/VlE Trading Bay Unit 9. WELL NO. Stat,,e,,,,G-16 (14-27) 10. FIELD A2qD POOL, OR WILDCAT ~:McArthur:~RiveN - Hemlock Zone 11. SEC. T. H., ~., (]~RDTTOM HOLE O~ECTIVE) Sec. 27, T9N, R13W, SM. 12. PERNIIT NO. 68-109 SUE~E(~;mNT REI'OaT o~: ~ ABANDON ME~T$ WATER 8HUT-oFF REPAIRING WELL ~ FRACTURE TREAT t [ MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT ,OR ACIDIZE II ABANDONS SHOOTING ~)R ACIDIZING ,. · REPAIR WELL CHANGE PLAN8 (Other) ~ (NOTE; RePort results of multiple completion on Well (Other) Completion or Recompletion Report and Log form.) 15. DEscRiBE PRopOsED OR COMp~ETED OPERATIONS (Clearly state all pertinent details, and give pertih~nt dates, including ~timated date of starting an~' propo~ work. : Tradin~ Bay Uni~ G-16 is an eas~ flank Hemlock producer.· ~ater produc~ion has been increasin~ and currently averages 191 cu~. t fluid entry test run indicates all ~he ~a~er entry ~o be comin~ from ~he bottom perforated interval. It is proposed to set a,~ire- line plu~ and dump cemen~ on Cop of plua ~o isolate ~he ~ater entry. ,. PROPOSED PROCEDURE: 1. Rig up portable derrick. 2. Run gauge ring and Schlum pkr flow meter to look for cross flow. 3. Set plug at approximately 13,157'MD (above bottom~:wet interval). 4. ThiS will give a l0 ft. cement cap on Make four wireline runs and dump cmt on plug. top of plug. Return well to production. ~ . May 15, 1970 ESTIMATED STARTING DATE' 16. I hereby certify that correct SIGNED ~ (Thi!space for State o~ce/41se)~ , Il ~ APPROVED BY CONDI~ION~ OF APPROVAL, I~ AH: TITLE Dist. Drlg. Su.pl;, DATE 4/23/70 TITLE /~/ /'~ ' DATE See '),nstrucfions On Reverse Side Approved ,COpy Returned Union Oil Compan''-'~' California union 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Telephone (907) 277-1401/~/~"~ Au§ust 15, 1969 Mr. Homer L. Burrell State of Alaska Division of Oil & Gas 3001 Porcupine Drive 'Anchorage, Alaska 99504 Re: TBUS G-16 Dear Mr. Burrell: Enclosed please find 2 copies of the directional survey of the above captioned well per your request of August 6 , 1969. BET/dp Enclo (2) Very truly yours, District Drilling Superintendent FORM 4131-AN~-W /R/R7~ FORM ~)69 4-63 PRINTED IN U.S.A. "tNION OIL COMPANY OF CALIFORNIA Document Transmittal No. TO AT STATE OF ALASKA Attn: Harry Kugler FROM G.H. L ~hb_auo___aum . 2805 Denali St., Anchorage AT TRANSMITTING THE FOLLOWING: 1 2" Senia & Blueline TBU G-16 ( I' DIVISION OF ¢ ill AND GAS Form No. P--4 REV. 9-30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS 0IL ~ GA8 [~ OTHER WELL WELL 2.NAME OF OPERATOR Union 0il Company of California 3, ADDRESS OF OPE~L~TOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99509 4. LOCATiON OF WELL Conductor #48, Leg #2, 1879' North & 1381' West from SE corner Section 29, TgN, R13W, Sm. 7. IF INDIA~, ALOTTEE OR TRIB~ H/~M~-_ ~ 8. LrNIT,FARM OR LEASE NA~E Trading Bay Unit 9. WELL NO. State G-16 (14-27) 10, FIFJ.2) A.ND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECT~ Section 29, T9N, R13W, SM. 12. PERAilT NO. 68-109 13. REPORT TOTAL DEPTH AT END oF MONTH, CHA~NGES IN HOLE SIZE, CASING ANT) CEMENTING JOBS INCLUDING DEPTH SET ~ VOLLrMES USED, PFA{FOP. ATIONS, %-ESTS A_N/) RESULTS, FISH/NG JOt~S, JLrN'K IN HOLE A~ND SIDE-TI~ACKED HOLE AN-D A3~Y OTI-IER SIGNIFIC~NT CliAl%IGES IN HOL~ CObFDITIONS. TRADING BAY UNIT STATE 0-16 (14-2.7), MAY .!_9.69 RIH w/DDrl & DDrld 12552' - 12602' sidetracking hole. RI w/d.a. & drld 8-1/2" hole 12602' - 13684'TD. Ran Schlumberger DIL, FDC, Sonic & LL-3 logs. Removed B0E & tbg head. Instld 12" 900 x 12" 900 cng head. Reinstalled BOE. RI to 13684'. Condition for 7" csg. Ran 325 its 7" 29# N-80 & P-110 buttress cs§. Hung w/shoe @ 13663 & DV collar @ 6171'. Cmtd around shoe w/300 sx CFR-2 cmt. CIP 10:00 pm 5/11/69. Open DV, circulate & W0C 8 hrs. Cmtd cng thru DV collar @ 6171 w/1000 sx "G" cmt. Good returns to surface. CIP ? A.M. 5/12/69. Removed BOE. Installed slips & packing. Landed 7" cng. Reinstalled BOE. Tstd OK. RI with 3-1/2" dp. Drld out DY @ 6171'. Drld out float collar & cmt to 13626'. Circ clean. Ran Lane-Wells Gamma Ray Correlation Log. Ran Sperry Sun Multi- Shot Gyro-Directional survey on wireline. RIH w/b~t & scraper. Drld out cmt to 13651'. Changed over from mud to fresh wtr. Circ clean. Spotted 90 bbls (2500') Magcobar protecto-mull inverse emulsion oil pill on bottom. PO, layed down all 3-1/2" dp. RU Dresser-Atlas, perfd thru cng: 12,844' - 12,884'1 12,904' - 12,985'i 13,005' - 13,088'; 13,108' - 13,142'~ 13,172' - 13,270'; Ran 413 its 3-1/2" tbg complete w/Camco g.1. valves w/Hydro set pkr. Landed w/tail @ 12,808' & Baker pkr @ 12,736'. Removed BOE. Installed Cameron tree. Tstd OK. Displaced wtr & protecto-mul~ pill w/diesel. Set pkr & tstd OK. Prep to place well on production via gas lift. RIG P~LE~,.S ,F.~. @ !:.30 P.M 5/16/69 d[, .., Il , , 14. I hereby certify that ~i~regoig ~l)~ftprrect, s~G~ __~=~ O's Drl . Su t ,,T~. 6/10/69 ... NOTE--Re~'ort On t~i$ form t/reqUired ~or each ca,endar month, r egardles, of the ,tatu~ of operations, ancl must be fi,e~ in duplicat[ with the Division of Mines & Min~als by the 15th of the succeeding month, unless otherwise directed. · ~ :fi? SUBMIT :IN DUPLICa'~...~ '~ STAT[ ~)[:-. AI,~SKA ~; (see other lu- ~ --- ~ ~;" ~ -~ ~ ~'~ structions on ~ WEhL~C~MPLETION OR RtCOM~itTiO~ R~B~T AhD LOG* : ~. TYPE OF COMPLE~ON: 5~ ~ ~ O;. ~,; ~ ?~ WELL ~ WOrK OVER ~ DEEP- ~::~ ~ . ~ Trading Bay Unit ~Sec~ion 29, TgN, R13~, S~. ' ~ c~ At top prod. Interval reported below ~ ~ ~. a~ ~. ~ ; ~ ;-' ~ .=J ~~) At total dep~ - ~, ~_. ~' ~ ~ 2043 S f 7893 E of surface location ~ ~i : · ~li~. 00 8' 1 t =.~ODUaHG ~~(I) OF ............ ' '-J- none ." ~a,mlock ~ 1397~ ~ 9523'VD ! :~ ' ' ' { :- - u~u, e'uu SONIC LL3, & GR-CBL j L~. ~ ~ .C~G ~ (Re~ all strings set ~ well) Ca~G S~Z~ ...... 17--3/4" U~ ~. (~) ~o~ S=~ - ~~~ ~CO~ .... ~O~ ~U~ 601 22"~ ~50 sX : "~J[' :' ~ hone 5960 1~"} ~50 sx 11 SIZE ..~none 28. (four 192 ~ 12844-1~ia 1290a-1~9~_ ~ 13005-~0~8~ (zvm~ ~0 13663 .300'i;:sx Bo"I"z'o~ (MD) s~zE (Interval, size and number) ! 13!08-13142 !31'72-13270 DEPTI-I.i LI~i~/~VAL .(MI)) -,.. TUBLIVG -:. DEPTH(SET (MI3) ! PEODUC'TION ~/S--i-~f t .. gas lif,. pumping--size andVtype o,.ptwnp) · DATE OF TEST, JI-~O~S TE~;l-j!a)-' "lC/tOKE SIZE IpROD'N ~~~ -'~J i24/64 j=s~~ j 1628 ~ - "~ :l ~. I zbz8 I : 716 I 86 t 31.0~ ~ 31. DISPOSITION OF OAS (~old, ~,e ' ~ 5/28/~ ! *(Se ide) (MI)) A~/iOUI~T ~'d~ID_,KIND OF 1VI~T'E/~IAL U.~'~ '- _ [~ELL STATUS (~ a~ut-in) ~' .. J,: producing none INSTRUCTiO?',~ S General: This forn~ is designed for subn~itt~ng a complete aqci correct we!i coe-plel~on report end tog on all types of lands and le~ses ~n A'l~sk~. .. ., Item: .16: Indicate wh~.h elevat,on is used as refere,w,~ (,vhe.'.. nol other,,se shc, wn'~ ~or depth me3sure- merits given ,n o~her spaces on this torn', and ~n any a~,~:;~'" er~s Items 20, and 22:: if ti~s well is compleled for separat,. ~)rc;i_,;'t::)n fro," ,~*ore than orhe ,ntervaJ :'one (multiple completion) so stale in item 20, and in item 2.°. show the p~c.flucir',9 int¢-rv, al, or' intervals, lop(s), bottom's) :;;d name (r.~ (if any) for only the intervt re!',orted ~n ~tem 30:' Submit a sepa..r, ate report (page) on ;h~s to;~,,, adequately idenlified, for each add,~,o, .. ;:,lu~vaJ ~o be sbperalely produced, show- '.. lng the ac~dilional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this wel.t"shoul,::t show the details of any mul- tiple stage cementing and the location of the cementing tool .... · Item 28: Submit a separate completion,report on this form for each. interval to be separately produced, (See instruction for items 20 and 22 above). , , ~'A'I'~:I(ANI) MUI) NAME ,,,,, NONE .' Ken. a 5 "C ' ,-Sam~ 484)' ~. .. "D" 5275' " "C ..... . 1!520' 8595' , . ,. ..' .-' iiem'loc, k 12840~ 9544 :. '. .We:st F'oreland 13670' 10083 . . ,. . .... ,. , . , . -. . . , , . - .... , ,. ~ .- ... . ~, . ., . . . . ~A'I'A, A'I'I'A('II llRIE'F D~qCRIPI'I'IONS ~()F [,ITIIOLOGY. POROSI.T~, FIIA(7~II~. APP~NT DIPS ' ' ANi) I)E'I'~:(?'t'~I)'SlIt)WS OF' OIL. OAS Oil 'WA'I'~: .~. i , i · , ... .. .. , ,.2 .. ,"258 (Il 12 ' -!2,277' ReCovered i9' conglomerate, bDfr. o. 3". ~.. pebs, med to ese. , it gry, tan, ang.-~d~ maSSive q'tz, v.lt. sta:rn, ~ull gold fluor., lt. brn, cu~ 5:~in~ ~o good 5odor, Good P-F. 'oipS o-35~ . . . . . . :.. Form J~- I001-A uniON OIL CO. Of CaLIfORNIA REPAIR RECORD LEASE TRADING BAY UNIT WELL NO. FIELD McARTHUR RIVER FIELD G-16 BEGAN. 3/29/78 COMPLETED: 4/9/78 PERMIT NO. 68-109 SERIAL. NO. ADL 18730 SHEET A PAGE NO. CONTRACTOR PARKER DRILLING CO. TYPE UNIT NATIONAL 1320 UE ELEVATIONS: GROUND 224' TO RT CASING HEAD COMPANY EI~GINEER He~sTWats0n ,o ,~ .... /' TUBING HEAD APPROVED~R~~ff' L_~f~-~v',,/~,//,~_.~.f,Z///_~/. ~ ROTARY DRIVE BUSHING ~ t0 MSL '/ ~/ CASING & TUBING RECORD ....... --m~ Z S DSPT~ Wg~ ~D~ .... ~gMX~Ks 17 3/,i" 601' .312 Wall Spiral "deld Spiral Weld csg - cmtd to surface. 13 3/~'' 5960' 61# J-55 · cmt'd w/1850 sx BJ Mix w 1/4# Cello seal/sx in 1st 1000 s 4500 sx CFR-2 preceeded by lOOfta fresh wtr. 9':~5/~'' 12,415' 40,43.5 17# J,55,N-80 Cmt'd w/lO0 sx. w/1% CFR-2 mixed w/ water 7' 13,6613 29# N-80 ' Cmt'd thru shoe w/300 sx CL "G" w/ CFR-2.cmt. w/lO0 sx "G 1/2 ~- thru DV @ 6171' .~ 12,805 9.2# N-80 '' See attached ~ubing detail. ' PERFOR, kTING RECORD DAT~. .... m.TF..,.RVAJ~ E.T.D. I .-REASON . PI:rESENT COND. I~ION . b/lb/b~ IZtJqq'-IZtJtJ4; i3,bJZ' FroQuctlOII Sqz:d w/400 sx c~ass .5/15/6! 12904'-12985' 13,632' Productioll Sqz'd. w/400 sx Class G lo-filtrate cmt. .5/15/6!t 13005'-13088' 13,632' ' Productioll Sqz'd w/400 sx'Class G lo-filtrate cmt. ]:5/15/6! 131.08'-13142' 13,632' Productioll Sqz'd d w/150 sx Class "G" lo-filtrate cmt. '5/15/6t 13172'-13240' 13,632' ' Productioll Open Hemlock Bench #9 8/20/7: 13,087' PrOduction 8/12/7~ 12860'-12880' 13.087' Productiol~ Sqz'd d w/400 sx Class "G" lo-filtrate cmt. '8/12/71 12922'-12'966' 13,087' .. Productiol~ Sqz'd d w/400 sx Class "G" lo-filtrate cmt. 8/12/71 13005'-13035' 13,087' " Productiol~ Sqz'd d w/400 sx Class "G" lo-filtrate cmt. 6/16/7,~ 13172'-13270' 13,095' ..:,- Injection Open Hemlock Bench #4 "· · ' · 7/18/7,~ 13200'-13270' 13,631 ::.~!'. Injection Open Hemlock Bench #4 INITIAL - ]]DATE ] INTERVAL NET OIL I CUT GRAV. C,P, T.P. CHOKE MCF OOR REMARKS " ' ' ' '~ ~4 · ' - ' ' ' : 4 /9/73 Bench ' '6500 BWPD ~ 3450 psi . :::::::.'.[ : . . - . . .-. COMPLETION DATE: ~RODUCING INTERVAL: INITIAL PRODUCTION' . . 3/78,~°nn BWPD _. LAST REGULAR PROD. & DATE: · CUMULATIVE PRODUCTION: ' REASON FOR REPAIR: .. ] SHEET PAGE UNION OIL OF CALIFORIIIA I',ELL I' ""' ' ,EuOt LEASE I'i~LL ,iO, G-16 FIELD DATE 3/29/78 3/30/78 3/31/78 4/1/78 4/2/78 ETD 13,663' TD 13,152' ETD (perm pkr) 9 5/8" csg @12,416' · 7" csg @13,663' 13,663' TD 13,482' ETD (junk pkr) 9 5/8" csg @12,416' 7"csg @13,663' 13,663'TD !3,154' ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,663' 13,663'TD 13,154' ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,663' 13,663'TD 13,154' ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,.663' DETAILS OF OPEP~TIONS, DESCRIPTIO~IS & RESULTS Commenced rig operations @12:01 a.m. 3/29/78. Moved Rig 54 over conductor 48 in leg 2 and RU. Loaded 3 1/2" tbg and 3 1/2" x 7" annulus w/ FIW and tbg went on vacuum. Installed BPV and removed 4 1/2" 5000# CIW double valve single block X-mas tree. Installed and tested to Union specs 12" 3000 Psi BOPE. Pulled 3 1/2" t(]b out of perm pkr @13,152' w/ 128,000# hook load and circ. hole w/FIW. Pooh and LD total of 429 jts 3 1/2" tbg. Found 1" hole @ top of pin end threads on jt #421 (approx 12,890'). Ran 6" od Tri-State'flat bottom pkr mill and three 4 3/4" DC on 3 1/2" DP. Finished RIH w/ 6" pkr mill on 258 jts 3 1/2" 13.30# Gr E & 160 jts 3 1/2" 13.30# S-135 DP to perm pkr @13,152' Milled up pkr in I 1/2 hrs andpushed junk to ETD @13,482' iprior pkr & ret junk). Circ hole clean and pooh w/ DP. RU Go Int. and ran 5 3/4" od gage ring and junk catcher on W.L. to 13,000'. Finished running 5 3/4" gage ring on Go Int. w.L. to 13,000' & pooh. Ran 7" Baker cmt ret on W.L. and set @12,828' Ran 7" Baker. retrievamatic on 3 1/2" DP to 12,500' and unable to set pkr. Closed BOPE and PI 3 1/2" x 7" annulus @24 CFM & 2200 psi. Pooh and LD pkr. Ran 7" Howco RTTS pkr on 3 1/2" DP & set @12,500'. Tested 3 1/2" x 7" annulus to 3000 psi --o.k. RIH w/ pkr and tagged cmt ret @12,828'. Pulled up to 12,818' and set pkr. Attempted to test cmt ret @12,818' & PI @ 14CFM & 2400 psi w/ partial return out annulus. Attempted to release pkr & backed off 3 1/2" DP. Screwed back in and pooh checking torque on each tool it. Ran new 7" RTTS pkr Ono3k1/2" DP & set @12,500'. Tested BOPE & lines to 3000 psi - . . Tested 3 1/2" x 7" annulus to 3000 psi -o.k. Set pkr & tested annulus to 3000 psi @12,6000' 12,692', & 12,784' - o.k. Set pkr @12,815' & pressured annulus to 3000 psi - bled to 2600 psi in 4 min w/ returns out DP. Moved pkr to 12,692' & pressured annulus w/ returns out DP. Pooh w/ DP. Ran 6" bit & 3 - 4 3/4" DC on 3 1/2" DP. Drilled out cmt ret @12,828' in 2 hrs, Pushed ret to ETD @13,482' and circ hole clean. Pooh. Ran 5 3/4" gage ring on W.L. to 13,200'. Ran 7" Howco cmt ret on. W.L. & set @13,154'. Ran 7" Howco RTTS on 3 1/2" DP and set @12,692'. Pressured 3 1/2"-x 7" annulus to 3000 psi - bled to 2600 Psi in 2 min w/ returns out DP. Moved pkr to 12,600' and repeated test w/ same results. Moved pkr to 11,677' and repeated test w/ same results. Pooh and. checked each tool jt w/ Martin-Decker torque gage on rotary tongs. S EET PAGE OIL CQ" ?/V-h' CALIFOF 'IIA ',ECORD I.i LL IlO, FIELD DATE ETD DETAILS OF OPEP. ATIONS, DESCRIPTiO~IS & RESULTS 6 4/3/78 7 4/4/78 8 4/4/78. 13,663'TD 12,596' ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,663' 13,663'TD 13,154'ETD (cmt ret) 9 5/8" csg @12,416' 7" csg @13,663' 13,663' TD 13,482' ETD (RET JUNK)' 9 5/8" csg @12,416 7" csg. @13,663' Finished pooh w/ 3 1/2" DP checking make-up .torque on each tool jt. Ran 7" RTTS pkr on 3 1/2" DP and set @1855'. -Pressured 3 1/2" x 7" annulus to 3000 psi and bled to 2600 psi in 2 min. Pooh w/ RTTS. Ran 7" Baker full-bore tension pkr on 3 1/2" DP and set @480'. Pressure annulus-same results. Isolated test system and tested BOPE to 3000 psi - o.k. Pooh w/ pkr and laid new squeeze line from squeeze manifold. Ran 7" RTTS pkr on 3 1/2" DP and set @1885'. Tested annulus and squeeze lines to 3000 psi - o.k. RIH w/ pkr and ~et @12,781'. Pressure annulus to 3000 psi & bled to 1650 psi in 3 min. Moved pkr ot 12,596' and tested annulus to 3000 psi - o.k. BD 7" csg leak 12,596' - 13,154' @12, CFM & 1600 psi. PI @18 CFM & 2550 psi - held 200 psi after 4 min w/ pump off. Squeezed csg leak w/ 300 sx C1 "G" cmt w/ .75% D-31, .3% D-19, .1% D-6 & 5% sand mixed @122 #/CF to lock-up @ 6000 psi w/ 37 CF of cmt in DP (488 of 525 CF displacement pumped). Pressure bled to 5000'psi in 40 min, and held. Released pkr and rev. out 40 CF cmt. CIP @6:00 p.m. Pulled pkr to 11,655' and pressure csg to 2000 psi w/ pkr hanging for 2 hrs. Released pressure and pooh. Finished pooh w/ squeeze pkr. Ran 6" bi't & three 4 3/4" DCon 3 1/2" DP to 12,000' and WOC total of 12 hrs. Drlg out hard cmt from 12,544' (11 CF backflow after squeeze) to cmt ret @13 154' in 12 hrs. Circ hole clean and pooh. Ran 7" Howco RTTS pkr · on 3 1/2" DP and set @1856'. Tested squeeze & 7" csg from 1856'-13,154' to 3600 psi w/ FIW for 45 min - o.k. Released pkr after testing squeeze and pooh. Ran 6" bit & three 4 3/4" DC on 3 1/2" DP and drlg up cmt ret @13,154'. Pushed ret to 13,482' and circ hole clean. Pulled up to 13,000' and closed BOPE. Established injection rate w/ FIW into Hemlock Bench 4 perfs 13,172' - 13,270' down 3 1/2" x 7" annulus @6.9 CFM or 1770 BPD. Pooh w/ bit. Ran 7" Howco RTTS pkr on 3 1/2" DP and set p. kr @13,158' .(Note: Pkr will not take wt. and hold in interval from 13,152'-13,157' - 3 pkrs set & drilled up in this interval). Offloaded acid & RU to acidize Hemlock Bench 4. $ EET PAGE UNIO!I OIL CCFP a .a' C.;F CALIFOPCIIA I-,£LL LEASE FIELD DATE 9 4/6/78 10 4/7/78 1:1 4/8/78 12 4/9/78 ETD 13,663'TD 13,482' ETD (ret junk) 9 5/8" csg @12,416' 7" csg @13,663' 13,663'TD 12,750' ETD (perm pkr) 9 5/8" csg @12,416' 7" csg @13, 13,663'TD 12,750' ETD (perm pkr) 9 5/8" csg @12,416' 7" csg @13,663' 13,663' TD 12,750' ETD (perm pkr) 9 5Z8" csg @12,416' 7" csg @13,663' DETAILS OF OPEPJ~TI~" uno, DESCRIPTIG~IS ~ RESULTS Finished offloading acid and RU w/ Halliburton to acidize. With 7" pkr set @13,158' between Hemlock Benches 3 & 4. acidized Hemlcok Bench 4 perfs 13,172'-13,270' down 2 1/2" DP w/ 4000 gal 15% HCL followed by 10,000 gal 12% HCL + 6% HF as fol 1 ows: Pumped acid to perfs (96 bbl FIW) Pumped 3230 gal 15% HCL into perfs Acid broke around blank between Bench 3 & 4 13,142'-13,172' Closed BOPE PI annul us w/ FIW PI DP w/ F IW Inc rate for remaining acid PI annul us w/ FIW PI DP w/ 12-6 acid 1.2 BPM & 3000 psi 1.2 - 1.8 psi & 3000 psi 2 9 BPM & 2700 psi 1.1 BPM & 2400 psi 1.2 BPM & 2100 psi 2.8 BPM & 2900 psi 2.5 BPM & 2700 psi Displaced acid to perfs and overflushed w/ 100 bbl FIW @2.5 BPM & 2300 psi. DP press bled to 600 psi in 3 min. & annulus press bled to 1600 psi and held. MOved pkr to 12,562' and RU Howco cementer to DP. Pumped 250 bbl FIW @4.5BPM & 3400 psi (6480 BPD rate @max platform inj press of 3400 psi). RU Go Int. W.L. and RIW w/ profile tools. Tools malfunctioned @ beginning of survey. Pooh and repaired tools. Finished repairing Go Int. W.L. injection profile tools on third attempt and RIH w/ W.L. Placed well on platform injection system @5836 BPD @3300 psi down on 3 1/2" DP &. below 7" retrievable pkr set @12,562'. Ran W.L. radioactive tracer survey indicating +3500 BP being injected into 63'Hemlock Bench-4 perfs 13,172'-13,270' wZ remaining +2300 BPD being injected above Bench 4.- Ran 5 15/16" gage ring & junk catcher on W.L. to 12,820'. Ran perm pkr w/ tail on W.L. and could not work below 1692'. Pooh & RD W.L. Ran 7" Baker Model FB-1 perm pkr w/ 6' millout ext, 15' seal bore ext.' i j.t 3 1/2'] butt tbg, & 3 1/2" Otis "XN" nipple on 3 1/2" DP and set pkr @12,'750' w/ "XN" nipple @12,803' Pooh w/ DP. Ran Baker Model G locator seal assy w/ 20' s~als on 421 jts (12,712')" 31/2" 9.2# N-80 butt tbg w/ ABC modified coupling and hydrotested each jt to 4000 psi. ._ Spaced out tbg in Baker perm pkr @12,750' and tested pkr in 1000 psi. Pulled out of pkr and displaced 7" x 3 1/2" annulus w/ 500 bbls Nalco Visco 938, 1153 & 3656 pkr fluid mixed in FIW accoridng to specifications. Landed tbg in perm pkr w/ end of tb§ @12,770', top of Model G seal assy @12,748', 3 1/2" Otis "XA" sleeve @12,719' and 3 1/2" Otis X nipple @337'. Installed BPV and ND BOPE. NU 4" 5000 psi double master individual valve X-mas tree and tested to UOCO specs. Modified injection line and placed on injection @6:30 p.m. w/ stab rate of 6432 BPD & 3425 psi @12:00 mid.. Released rig from TBUS G-16 @12:00 mid 4/9/78. SHEET PAGE UHION OIL CCI. / IY CF CALIFO IIA I' £LL I' ECOt LEASE TRADING BAY UNIT STATE l'~LL IlO, G-16 HESS FIELD McARTHUR RIVER FIELD 4/9/78 AFE: 381402 ! DATE JTS. 1 412 9 DETAILS OF OPEP. ATIONS, DESCRIPTIO~IS & RESULTS 3 1/2" 9.2# N-80 TUBING W/ ABC MODIFIED COUPLING DESCRIPTION LENGTH BOTTOM TOP Baker mule Shoe Baker Seal Assy Baker Locator 3 1/2" 9.2# N-80 Tubing 3 1/2" Otis XA Sleeve 3 1/2" 9.2 # N-80 Tubing 3 1/2" Otis "X" Nipple 3 1/2" 9.2# N-80 Tubing 3 1/2" 9.2# N-80 Pup 3 1/2" 9.2# N-80 Pup 3 1/2" 9.2# N-80 Pup 3 1/2-" x 4 1/2" Butt X-Over 4 1/2" Tubing Hanger Landed Below K.B. .60 12,769.90 12,769.30 19.30 12,769.30 12,750.00 .80 12,750.00 12,749.20 29.70 12,7~9.20 12,719.50 4.00 12,719.50 12,715.50 12,378.38 12,715.50 337.12 1.15 337.12 335.97 270.27 335.97 65.70 10.21 65.70 55.49 10.17 55.49 45.32 6.22 45.32 39.10 .70 39.10 38.40 1.00 38.40 37.40 37.40 O0 Baker Mule Shoe 3 1/2" Otis XN Nipple 3 1/2" 9.2# N-80 Tubing 4 1/2" Butt x 3 1/2" Butt XO Seal Bore Ext Connector Sub Mi 11 out Ext Baker FB-1 Prod Pkr .67 1.34 30.28 .38 13.47 .83 5.40 2.65 12,805.02 12,804.35 12,804.35 12,803.01 12,803.01 12,772.73 12,772.73 12,772.35 12,772.35 12,758.88 12,758.88 12,758.05 12,758.05 12,752.65 12,752.65 12,750.00 Form D- 1001 UN:ON O. IL CO. OF CALIFORNIA REPAIR RECORD SHEET A' PAGE NO. LEASE T,~a.l;,,g FIELD PERMIT NO. COMP.A'~Y ENGI:<EER ~" ~ ..... . '~ ' . ................. .... WELL N ~: , O._G::lu_ CONTRACTOR ........ I)'i'i].].j~ Co. TYPE [INIT .., ,~. ,. · . _ ........ L~O_...l.~a~~l ELEVATIONS: OROUND .. ~ ...... CASING }lEAD i'revJ, ou5 TUBING HEAD ................... ] 'istorY ROTARY' DRIVE BUSHING CASING & TUBING RECORD SIZE DEPTH WEIC. HT Gn~DE REMARKS 'i7 3/4" 15 3/8" 9 5/8" 7~ 601' 5960' 12,416' 15,663 ' .512 "' "- tval± 0,43 5 ~' "' . 29# 5pira! tie] J-55 N-60 Spiral held csg.-~mt'd to surface. Qat'd w/1850 sx, ~ mix w/ 1/,I' r' c ~ - ,)0v~ '~ ,,' ~ell9 ~ea~/sx. :i.n Ist ]. sx ~ S00 sx. CFR-2 preceeded by 100 ft."fresh wtr. Cmt'd w/ 100 sx. w/ ].~ CFR2 m~:ed w/ ~r. ~t'd thru shoe w/ 300 sx. CFR2-"G" ant. w/ 1000sx. "G" thru DV 0 6171' See Attachgd Detail, D_A TK. _ s/is/os 5/15109 s/is/os .s/is/ss s/ z/ s 6/16/74 7/18/7q 12,844 ' -12, $84 or:,', 985 12, ~_.,~ -12, 13,005 ' -i3,088 13,t08 ~-]_3,142 i3,172'-13,240 12,860'-12,880 12,922'-I~,966~ 13,005'--i3,035 15,i72'-i3,174 13,200'-13,270 ]_3,632' 15,032' 13,032' 13,632' 63~' 13,087' i3,087' !5,087'' 13,087' 13,095' i3,63!' Production Product J on Production Production P. rod~ction Production Production Production Corem. Test Injection PRESE~. Sqz. w/ 400 sx. Class "6" Lo-filtrate S(Iz. w/ 400 sx. Class "G" Lo--f ii. irate Sqz. w/ 400 sx. Class Sqz. w/ 1S0 sx. Class "G" Lo-filtrate Open Hemlock Bench Sqz. w/ 400 sx. Class "G" Lo-filtrate ont. Sqz. w/ 400 sx. Class "C" Lo-filtrate cr:t. Sqz. w/ 400 sx. Class "G" Lo-filtrate &pen Eemlock Bench it4. Open l-lemlock I~ench ~4. DATE [,bred INTERVAL b~ck over G-l( NE~TQJL On C-II ~ 1210! tmi, (~ 12'0 i)m, /10/74 INITIAL PRODUCTION AFTER ~aAV. c.P. T.P, cHc ,~] , /10/74 Relcz sed md comj lcted )perat .ohs ~ 1 GOR 1 1 1974 OIL AN~ ORAGE .4 0 12' ~ ~OO~ , , B~KS GAS WELL HISTORY PRIOR TO REPAIR COMPLETION DATE: 813117'2 LAST COMPLETION NO. I\O ~,': 2 PRODUCING. NTEWVAL:____~.x~ :~_:; -_ ~u~._~='""' '-' '~ ..... :-: ~" ~.:" ~-: '"' INITIAL Pi'IODUCT'iON' -t,j~ ........ ~-':',t"!'~,./ .... 67~~0~_5./~t~,4_~__~,-,--~- ~-, -/ ~',/6'~ :9 ........... 4% cut LAST REGULAR PROD. & .... *~-~ .... : .. ~:-~± ...... L_i~_~0_.::,."'.~ c'.-_:.._~/~.x~ ..... ~.~_Cut ~ rr~? ,, r ,~ t~' ,1~: '- . " ~ q-'~ ,'~ . -, - ,. Form D- 1001-B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO. DATE E.T.D. .WELL NO. G-10 FIELD [fe5rthur River t:ie]d APPROVED__ J.i~[ P.. Caf]_e~d. er DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DEC DIVI$1C;N Off OIL AND OA~ ANCHORAGE TYPE: CASING HEAD: ,J[~ffer tJ3 w/2" SI~ outlets - 12" CASING HANGER: ,maJ~fer 12" nom. 9 5/8" }~bdcl uu0 w/ 2" Phmgeu outlets. CASING SPOOL: Cameron i2" "" " .... 7 [. BING HEAD: TUBING HANGER:_:' '-~'-P'~" nom. 4 ]./2" Buttress S" ~,:'ic stri~:, sol. id ]';lock lop- tv',~' w/ ],iakcr ,, swa.~: v;~.~ .c ]:;l:m. c, ~,,,,t~ TUBING HEAD TOP. N "~ c " .... . MASTER VALVES: CHRISTMAS TREE TOP CONN.:_ 4 ],/2" ]!lit! "-xUll [U[i bi L L:U iT UiL[t :U d kiLL i [.~E TRADING BAY UNIT STAII~ I;[-'U_ ID, c- 16 F IEU) McArthur River Picld DETAILS OF OPE_RAT[OIlS, DESCRIP!!O!!S &R_E_S_ULTS .. 6/10/74 13,684'TD 13,087 'ETD Cmt. above ret. @ 13,098 ' 6/11/74 13,684'TD 13,087 ' ETD 6/12/74 13,684'TD 13,087 'ETD 6/13/74 13,684 'TD 13,087 'ETD 6/14/74 13,684'TD 13,087 6/15/74 13,684'TD 13,631' 6/16/74 13,684'TD 13,095: Cant. Ret. 6/17/74 13,684'TD 15,155 Cnm. Ret. 6/18/74 13,684'TD 13,462 'ETD Cant. Ret. 6/19/74 13,684'TD 13,462 Cmt. Ret. 6/20/74 13,684'TD .13,462 'ETD Cmt..Ret. (Footage 0') Commenced operations on Platform @ 12:01 am, 6/10/74. RU on TBUS G-16. Loaded out 5" DP. Skidded rig from well no. G-8 to G-16. Pulled bali valve @ 272'. Loaded annulus w/ filtered Inlet wtr. SI annulus. Pm~ed 15 bbls of diesel & 115 bbl~.,of, filtered Inlet. wtr. dwn. tbg. (Footage 0') 24 hr. offloading invermul from platform. Cleaning mud tanks and onloading 3 1/2" DP. (Footage 0') Completed cleaning invermul in mud tanks and drlg. decks. Installed BOPE ~ tested to UOCO specs. Tied into 3 1/2" tbg. & unseated hyd. pkr. @ 12,755'. Iiole taking fluid @ a rate of 20 bbls/hr. (Footage 0') Pulled & laid dwn. 3 1/2" tbg. & accessories. RIH w/ 6" bit ~ 7" csg. scraper. CO fill from 15,017' to 13,087'ETD. Circ. btms. up. Pooh. * (Footage 0') Pooh w/ 6" bit & scraper. RU WL unit & ran guage ring to top of cmt. plug @ 13,087'. Ran EZ drlg. cmt. retainer & set @ 12,798 to squeeze off Hemlock Bench #1 & #2 perfs. Ran 5 1/2" DP & set into re- tainger @ 12,798'. Squeezed perfs, from 12,844' to 13,087' w/ 400 sx. Class "G" Lo-Filtrate cmt. to final pressure of 5500 psi. Ran 6" bit. Drlg. out retainer @ 12,798' ~ firm cmt. opposite Bench #1 & #2 perfs. (Footage 0') Drlg. out retainer @ 13,098' above Bench #3 perfs. CO well to 13,462'. RUWLunit [ ran CBL-GR Log from 13,400' to 12,600'. (Footage 0') Perforated Hemlock Bench #4 from 15,172' to 15,174'-4 hpf. t~m EZ drlg. retainer & set @ 13,155' Ran 3 1/2" DP [ set into retainer @ 13,155'. }hd communication between B~nch #4 [ Bench #5 perfs. Spotted 6 sx sand on .top of retaine~ @ 13,i~5' & Pobhw/ 5 1/2" DP. RU WL unit. Ran EZ drlg. retainer & set @ 15,095' to squeeze Bench #3 perfs from 15,108' to 15,142'; (Footage 0') RIH w/ retainer stinger on 5 1/2" DP. Set into cmt. retainer @ 13,095'. Squeezed off Hemlock Bench #3 perfs from 15,108' to 13,142' w/ 150 sx. Class "G" Lo-Filtrate cmt. to a final pressure of 5800 psi. Pooh. Ran 6" bit. Drlg. out retainer @ 15,095' & firm cmt. opposite Bench #3 perfs. Tested perfs to 2500 psi-ok. Washed sand off top of retainer @ 13,155'. Pooh w/ 6" bit. (Footage 0') TIH w/ retainer string & stabbed into retainer @ 13,155'. Attempted to test Bench #4 & blank between Benches #3 & #4. Unable to test due to slow con2unication between DP & csg. Had indication that seals on retainer were leaking. Pooh. TIH w/ bit [ drlg. retainer @ 13,155 Pushed to 13,462'. Pooh. (Footage 0') Completed Pooh. RIH w/ RTrs & set @ 15,158'. tIeld 4250 psi on DP. tlad slight bleed off into Bench #4 w/ no communication around blank to Bench #3. Released RTrs & Pooh. Rigged up & Perforated Bench #4 from 13,172' to 13,270' w/ 4" csg. guns @ 4 hpf. RIH w/ 6" bit & 7" csg. scraper to 13,400'. Changed over ~tr. in wellbore w/ clean filtered Inlet wtr. Pooh. (Footage 0') Completed running 3 1/2" 9.2# N-80 Buttress tbg. & spaced out. Ran WL collar locater & found pkr. 10' high to DIL measurements. Added 10' ptp jr. & spaced out. Circ. well & displ. annulus filtered Inlet wtr. ~ .5% visco S-55A inhibitor. Set Baker Model M{ hyd. pkr. @ 13,156'DIL measurement. Tested pkr. to 3500 psi from below-ok. Removed BOPE & installed x-mas tree. Tested tree to 5000psi-ok. [~I~ ~ ~0 ~~ t'AGE ih, WELL l lu, G- FIELD McArthur River Field 6/21/74 15,684 'TI) 13,462 ' Out, Ret. 7/16/74 13,684'TD 13,631 · ,DETAILS OF OPERATI0{~S,. DESCRIPTIOI!S &RE_StiLTS, (Footage 0') Completed rigging up to inject xctr. Injected into l!emlock Bench #4 @ approximately 150 BPD w/ 3500 psi. Skidded rig from TBUS G-16 to TBUS G-14. Laid dwn. 3 1/2" rental DP. RELFASED RIG FROM G-16 TO G-14 @ 12:00 NIDNITE, 6/21/74. (Footage 0') Commenced operations on TBUS G-16 @ 12:01 pm, 7/16/74. Skidded rig from G-14' to G-16. Installed BPV. Removed x-mas tree. Installed & tested BOPE. 7/17/74 13,684'TD 13,631 ' 7/18/74 13,684'TD 13,631' 7/19/74 15,684'TD 13,631 7/20/74 15,684'TD 13-,631 7/21/74 13,684 '.TI) 13,631' 7/22/74 13,684'TD 13,631' 7/23/74 13,684'TD 13,631 ' ];TD 13,684'TI). 13,631'E~3 (Footage 0') Pulled 3 1/2" tbg. & accessories. PU'3 1/2" DP. RIH w/ 6" bit & ·7" csg~ scraper to 13,400'. Circ. well clean. Pooh. (Footage 0') RIIl w/ RTTS & RBP. Straddled Bench #4 perfs from 13,1.72' to 13,270'. PunPed.into perfs @ 4 cu. ft./min, w/ 4500 psi. No co)Fmmica- tion around blank 1~,142' to 13,172'. Tested squeezed perfs in Benches '#1, #2 & #3 w/ 2500 psi ok. Released R?TS q retrieved RBP. Pooh. ~) Schlumberger & reperf, bt'70' of the Itemlock Bench #4 from 13,270' to 13,200' w/4" csg. gmxs @ 4 hpf. (Footage 0') RIH w~ RTTS & set @ 13,157". Tested 30' blank between Benches #3, #4 w/ 4500 psi differential. Tested squeezed Benches #1, #2 & #3 to 2500 psi-ok. RU Dowell. (Footage 0') Acidized Bench #4 w/ 4000 gal. 12-3 hud acid & 800 gal. F,-95 solvent, chased w/ filtered Inlet ~¢tr. @ 5.5 BP~.$ w/ 7500 psi. l.hloa, ded & mu frac. equipment. Hixed ~) 500 ~b'ot ~s of '~r uu~-~ ~'..~"~' frac. fluid. Tested frac. equipment to 9000 psi-ok. Frac. IIemlock Bench #4 perfs from 13,172' to 13,270' as follm~;s while holding 25~0 psi on mtnulus. VOLUI'~'~ STAND CONCD~P4ITION PATE PPJ!.SS. ~ls iD - ii~ 5 ])biS/rain' 8200 psi 119 bbls 1/2#/gal. 10 bbls/min 8400 psi 119 bbls 1#/gal. 9 bbls/min 8500 psi 89 bbls 1 1/2#/gal. 9 bbls/min 8500 psi 7 bbls* 1 1/2#/gal. .S bbls/min 8900 psi *Sm~ded out. Stopped frac. w/ press, increasing. Total volume into perfs 502 bl>ls w/ 13,500# sm~d. (Footage 0') Released RTTS & rev. out sand in DP. Reset RTTS & RU to plat- form wtr. flood. Unable to inject into Bench #4 W/ 3450 psi. Pooh. Rltt w/ 6" bit & 7" csg. scraper. CO sand fill from 13,191' to 13,462'. Circ. hole clean. Pooh. (Footage 0') Ran P3TS tool & set @ 13,158'. Established stabi].Jzed in- jection rate of 1820 BI;YD w/ 3450 psi into Bench #4 using platfom injection system. Pooh. Laid d~m. 3 1/2" DP. RII Schlumberger. Ran I',% jtm]..: bas]:et to 13,200'-ok. Lost JB off lq. M~ile Pooh @ 5800'. Pan I'.~. locater G found JB @ 13,172'. Unable to pump &,m. hole. (Footage 0') Pooh w/ Itl. locator. Rill w/ 6" bit. Tagged top of l'J, fish 13,172'. Pushed to 13,191'. Pooh. Rib w~ overshot Ii worked over fish @ 13,191'. Pool~ & rec. fish. (Footage 0') Ran bit & scraper to 13,600'. Pooh. Rigged up Schl~nberger. Ran junk ba.sket & gauge ring to 13,200'. Ran Baker bbdel "F" pkr. & se~ DEC 11 lira-- DIVI~tCI,~ OF Oit. AND ANCHOIIAO! LEASE YELL i,ECOi~ TRADING BAY UNIT STATE I;LLL l.lu, c,-~6FIELI1 ?cArthur River Fiel. d ~~S__ :-!S£RIPTIOI~S g 7/25/74 13,684'~3 (Footage 0') Ran 3 1/2" tbg.-hydro-tested to 6000 psi. Stabbed into perm. 13,631'ETD pkr. @ 13,152'. Tested-ok. Spaced out-&, landed tbg. Installed BPV., remov- ed BOPE. Installed & tested x-mas tree to $000 psi. Released rig @ 12:00 Noon, 7/2S/74 for deactivation. FINAL REPORT Now: Deactivating rig. OEC ~i ~ ~, DtVI~ION C,P tD.I,, i,~ gAS ANCHOItA~:, I:LLL LEASL Trading Bay Unit State L1 LL lIu G- 6 FILU) llcArthur River Field ___~_ ....D_F~TAILS OF_OPE.~PCkTiOLIS,_D_ESaRIP~TIOJ,S & RE.S_U. LTS ~JBING DETAIL · ,ITS. LENGTI I PkOTT~ 'I TOP 3 1/2" Baker Mule Shoe 3 1/2" 8rd X 3 1/2" Butt. I IXO! ! 3 1/2" Otis "Q't nipple 3 1/2" 9.2# N-80 Butt. Pup 4" Baker Locater Seal Assy. 3 1/2" Baker Locater Sub, 3 1/2" 9.2# N-80 Butt· Tbg. 1 3 1/2" Otis "XA" sleeve 3 1/2" 9.2# ~J-80 Butt. Tbg. 428 3 1/2" 9.2# N-80 Butt· Pup. 3 1/2" 9.2# 'N-80 Butt. Pup. 3 1/2" X 4 1/2" Butt. "XO" .4 1/2" Butt. Btm. X 4 1/2" 8rd top Cameron I~g. }.Imlger Landed 37. S0' below zero 0.85 13185,69 13184.84 1.30 13184.'84 13183.54 0.87 13183;54 13182.67 10.98 13182.67 13171~69 19.80 13171.69 13151.89 0.77 13151.89 13151.12 31.04 13151012 13120.08 5.81 13120.88 13114.27' 13057.29 13114.'.27 56.9~ 10.'05 56.98 46.93 8.10 46.93 38.83 0.33 38.83 38.50 1.00 38.$0 37.50 37.50 37.50 -0- 429 Jts. of 3 1/2" 9.2// N-80 Buttress. Tbg. used Baker blule Shoe Otis "Q" Nipple Otis "XA" Sleeve 3.97" OD X 2. 875" ID 3.75" OD X 2.656" iD .i.Z5" OD X 2.7.5" ID Baker bbdel F-1 Pkr. 4" Bore set @ 13,152'. DEC Ol,Vl$1Ol~l CF OiL A~ GA~ ANCHORAGE OIL. CO. · WELL REPAIR C., H t-: L::'F A PAOr: Ho..__1.__. 7/25/74 TUBING DATA- 3 1/2" 9.20# N-80 Buttress tbg. to 13,186'. TUBING ACCESSORIES: 1. 3 1/2" X 4 1/2" Butt. "XO" sleeve, 38'. 2. 3 1/2" Otis "XA" sleeve 4.25" OD X 2.75"ID, 13,114'. 3. 3 1/2" Baker locater sub, 13,151'. 4. 4" Baker locater seal .assy, 13,152~ S. 3 1/2" Otis "~" nipple, 13,183'. 6. ~ale shoe, 13,185'. 5960' 13 3/8" 61# J-SS Seallock cmt'd to surface. 12,416' 9 5/8" 40t/,43.5ti, 47#, J-SS & N-80 Buttress. Baker F-1 Pkr. 13,152'. wliLL SCI ~\[ITIC · . TP~DING BAY UN.IT STA'I~ G-16 13,663' 7" 29// N-80 Buttress DV @ 6171'. 7/25/74 ~w~__ c~. AII'J"D. iii ~1 ...... · Il I I II Il I J_ Il _ ~ Illlllq UNION OIL COMPANY OF CALIFORNIA i i ! II ~ TUBING tIEAD TOP: MASTER VALVES: Single string sdlid block log t}q~e w/ hinter' and/swab valve.. to 5000# w/ 7" OD seal pocket.. Bottom fl;role CItR!STMAS TRFE TOP CONN.:.__ o. 4 1/2" DYE UNION OIL CO. OF CALIFORNIA tfl2LL REPAIR SHEET D PAGE NO, , LEASE Trading Bay Unit State _WELL NO.. G-1,6WO_.FIELD. ;.~,cArthur River Field DATE 8/25/72 8/26/72 8/27/72 8/28/72 8/29/72 8/30/72 8/31/72 E. T. D. 13,684'T] 13,632'E' 13,684'T] 13,632'E' 13,684'T] 13,632'E~ 13,684 'TI 13,632 13,684'T 13,632 'I5 13,8.64 'Ti 13,632 'Et 13,684'T 13,632'E' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Conunenced operations at 12:00 Noon, 8/25/72. · l~loved rig 'from Trading Bay Unit State G-12 to Trading Bay Unit State G-16. Rigged up Otis. Pulled ball valve. Attempted to open "XO" sleeve at 12,700' above packer. · Continued to try to open "XO" sleeve at 12,700', without success. Rigged 7D do~m Otis. Rigged up Dresser Atlas. Shot 3 1/2" holes from 12,725'. Unable to circulate. Shot 7-1/2" holes from 12,688' to 12,690'. lhable to circulate. Shot 2- 1/2" holes from 12,706' to 12,708'. Circulated. Changed over to inverm.~ul and killed well' Installed DPV and removed x-mas tree. Installed and tested BOPE, choke and kill ].ines. lMseated pa. ckbr. D Circulated bottoms up. Pulled 3 1/2". tubing, packer and accessories. RIH w/ 6" bit and 7" scraper,.picking up 3 1/2" drill, pipe. TIIi w/ 6" bit and 7" casing scraper to 13,200'. cir~]]lated and conditioned D invermul to 68#/ cu. ft. Pooh. Rigged. up x~ireline unit and set tDI'EO EZSV cement retainer at 13,093' I~. P~an retainer stinger on 3'1./2" DP and tagged into retainer at 13,098'. Unable to breakdmm belm~ retainer with 2500 psi - held.pressure for 30 minutes - ok. Spotted 20 sacks of cement "C" w/ 1% D-31 on IIOWCO EZ drill retainer at D 13,098'. Pulled to 13,080' s/ 3 1/2" drill pipe and reversed out ].5 cu. ft. of excess cement. WOC. Rill ~ bit mud scraper. RII!. Found hard cement at 13,087'. Pooh, Prepared to rrm tubing. Ran and landed 411 jts. of 3 1/2"N-80 Buttress t~)inR, with Baker hydraulic packer hanging at 12,733' and 11 gas lift valves in place. Set packer and tested same with 3000 psi - ok. Installed BP~. Removed PDPE. Installed Cameron Christnms tree. Tested tree w/ 4000 Psi - ok. Opened "XO" at i2,637'. Displaced inverm'~l ~ diesel i~ annulus and tt~inR. Closed sleeve. Tubing tested - ok. (tested to 2500#. Ri~ged do~n Otis. Released rig for move to G-9 at 9'00 am, 8/31/72. Now producing well for clean up prior to acid stimulation. .J UNION OIL CO. OF CALIFORNIA h~BLL REPAIR SHEET PAGE NO LEASE_ Trading Bay Unit State WELL NO G-16WO F D ;?cArthur River Field IEL DATE E. T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS TUBING DETAIL 3 1/2" Baker Shear Sub 3 1/2" N-80 Buttress Tub.ing 3 1/2" Otis "X" Nipple 3 1/2" Buttress Collar 3 1/2" N-80 Buttress Tubing 3 1/2" x 7" Baker ttyd. Packer 3 1/2'.' N-80 Buttress Tubing 3 1/2" Otis "XO" (Right side-up) 3 1/2" N-80 Buttress Tubing 3 1/2" Otis "XO" (Upside dram) 3 1/2" N-80 Buttress Tubing 3 1/2" Camco KBMG ~Iandrel #1 3 1/2" N-80 Buttress Tubing 3 1/2" Cm~co KPJ4G Mm~rel #2 3 1/2" N-80 Buttress Tubing 3 1/2" C~nco kqhMG Mandrel #3 3 1/2" N-80 Buttress Tubing 3 1/2" Cmnco KBMG Mandrel #4 3 1/2" N-80 Buttress Tubing 3 1/2" Camco KI~IG biandrel #5 5 1/2" N-80 Buttress Tubing 3 1/2" Camco KL~4G Mandrel #6 3 1/2" N-80 Buttress Tubing 3 1/2" Camco KI~4G ~.hndrel #7 3 1/2" N-80 Buttress Tubing 3 1/2" Camco kq~'4G Mandrel #8 3 1/2" N-80 Buttress Tubing 3 1/2" Camco KB},IG Mandrel # 9 3 1/2"'N-80 Buttress Tubing .3 1/2" Camco KB~IG Mined.tel #10 3 1/2" N-80 Buttress Tubing 3 1/2" C~co KI~IG Mandrel #11 3 1/2" N-80 Buttress Tubing 3 1/2" Otis Ball Valve 3 1/2" N-80 Bittress Tubing CIW tlanger and 4 1/2" Buttress x 3 1/2" B~.t. tress X-over. Landed Below Zero JTS. I~,NC/II ! . 1 1 2 1 9- 8 9 8 10 :20 34 47 7i 93 89 1.43 31.41 .70 .80 28.66 7.18 29.43 3.70 58.87 3.88 29,74 8.10 278.43 8.10 247.55 8.10 277.25 8.10 250.19 8.10 314.99 8.10 621.24 8.'10 1054.42 8.10 1462.44 8.10 2158.16 8.10 2877.70 8.10 2690.70 5.10 242.39 1.00 37.00 TOP 12,803,46 1.2,802.03 12,770.62 12,769.92 12,769.12 12,740.46 12,733.'28 '12,703.85 12,700.15 12,641.28 12,637.40 12,607.66 12,599.56 12,321.13 12,313.05 12,065.48 12,057.38 11,780.13 11,772.03 11,521..84 11,513.74- 11,198.75 11,190.65 10,569.41 10,561.31 9,506.89 9,498.79 ' 8,036.35 8,028.25 5,870.09 5,861.99 2,984.29 2,976.19 285.49 280.39 38,00 37.00 -0- · Tubing l Tang~ Ball Valve 280 ,ID=2.313 3 1/2" CX Gas Lift Handrels- CX blandrel #1 - 12,560' CX b, landrel #2 - 12,313' CX bl-andrel fi3 - 12,057' CX Ma~drel #4 - 11,772' CX Mandrel t~5 - 11,514' CX Mandrel ti6 - 11,191' CX Mandrel #7 - 10,561' CX Mandrel ~8 - 9,499' CX Mandrel #9 - 8,028' CX Mandrel #10- 5,862! CX ~.~ndret #11- 2,976' 3 1/2" Otis-XO- 12,637' ID=2.313 ' 3 1/2" Otis XO - 12,700'. ID=2.313 3:;1/2" Shear Sub - 12,770'. 3 1/2" X Nipple - 12 _802'. ID=2.750 Tail Btm - 12,803'. TD - 13,684' iTD - 13,087' FORM 2.4'7 {NEW 5/66) ~ la ,, I I I I N' _] I · [ · t'~rEI,L SCtlD,~,TIC O' 37.00' 601' - 17 3/4", .312 Wall, spira] weld, slip jt. - Cmt'd to 'surface. 5960' - 13 3/8" 61# ,1-55 Seal. Lock cmt'd to surface. 12,416' - 9 5/8" 40# 43.5# 47!! J-SS an N-80 Buttress. 12,733' - 3 1/2" x 7" Baker IIyd. Packer. LIS · DV ,663' - 7'"29# N=80 Buttress. at 6171'. G-16 WO 8/3/72 : j il [ T ,~ ~- ' F [ il! ......... I I _ I I TBUS G- 16 4 1/2" x 3 1/2" X-Over @ 38' OTIS SAFETY VALVE IN 3 1/2" "X" Nipple @ 336" _17.3/4" C. 601" 13 3/8" C. 5960' 9 5/8" C. 12416' 3 1/2" OTIS "XA" SLEEVE @ 12716 BAKER FB-1 7" x 4" PACKER @ 127.50 3 1/2" OTIS "XN" @ 12803' 3 1/2" Mule Shoe Guide @ 12805' 7" C. 13663' ~m~ I ,--A~-~o~f McARTHUR RIVER I ..... TRADING BAY UNIT STATE G - 16 ' I Started 3-29.7'8 Completed 4-9-78 I ' - = * i i _ i ! i iii 247 (Nr:'- W 5/66) CONTRACTOR RIG NO, RIG MAKF , _ COLLARS: OD X ID X LENGTH ~~O. / DAY / YR. T.P.-DRILLERS COMPANY FIELD ...... RIG SIZE X X LEASE. WELL NO. '~J~' ~ ~ PUMP NO. I ~.X.~X UNDER SURFACE / / ~A~ ............. COUNTY~ PUMP NO. 2. DRILL PIPE UNDER INTER. __/~/ WATER SOURC~ T'gHIP/SA~tGE MUD TYPE. TOOL JOINT. TOTAL'DEPTH / / FUEL SOURer Ti ,, II I ' J JETS - 3~nds' J DEPTH CUM. PUMP PUMP NO i PUMP NO. 2~ MUD PROPERTIES Dev. DulI. Cond. l~ 1/8 FEET WT. Ver.2 ~ SERIAL .. Reg. R or RO OUT FEET HOURS PER HOURS I000 R.P.M. PRESS. H~: ~1~ MAKE TYPE NO. 1 2 3 HOUR LBS. T B G ~,.~ ................. Liner SPM L~ner SPM Wt. ~L.~F.V.jp~=IY~P. _ ...... ~ ......... .... ...... , . . ................................... , .... ........... ~ - , , , . , , ~ .............. ~ - , ~ .... ............. ................ , Trip icate Form GET ~IN YOUR DRILLING Form No. S · , . , I .-O.''~ ..~00 0~ i 'A" 3000~ UN.DN _ - OIL CO. OF CALIt/"")RNIA DRILLING RECORD LEASE_Trading Bay Unit State WELL NO.. G-16 FIELD McArthur River Field LOCATION Leg 2, Conductor 4~ 1879'N, 1381'W of SE, corner Section. 29, T9N, R13W, ..SM, , SERIAL NO 68-109 T.V.D. PERMIT NO. 68-109 T.D. _13,784' DEVIATION' (B.H.L.) SHEET A PAGE NO. SPUD DATE '1/6/69 ~ COMP. DATE 5/16/69 CONTRACTOR. WODECO " RIG NO. 54 TYPE UNIT National 1320'UE Ro'tary DRILL'PIPE DESCRIPTION. 5" x hole ELEVATIONS: VCATER DEPTH· 125,O0 R.T. TO OCEAN FLOOR 235.60 R.T. TO MLLW 110.60 "~, R.T. TO DItILL DEl ]K 19,30 R.T. TO PROD' 42.60 COMPANY ENGINEER APPROVED: ~ (B. E. Talle¥) · BIT JET DEPTH VERTICAL DATE DEPTH N.O. SIZE MA.K,E .... TYPE, sIZE OU,.T FEE..T HOUI~S A~I,~. J DIRECT.IO~TAL 1/6/69 0 1 15" HTC 0SC3 '3-24 615 615 5 60 - 7 ~" 615 1RR "' ' !' .... %" - " " ..... CO cmt ' ' ' : ... .... 9" 615 2RR '12-1/4" 'Reed YT3J' ' '" ' ' 874 2'59 5 .80 '- DDrld 9. ' I 8..7.4 2RR i, ..... ,, ,,~ 3_12 '1574 700 5 i2'0 426 ' ...i i0.. 1574 2RR "'' -" " '" 3-24 1765 191 4 90 "Dd'rid ...: 10 1765. 3 ' .. "... " Sec S3'5J 3-14 26'~8 '843 8 120" 4-26' .. .. 11 2608 4 " Smith DTH " 3565 957 9 " " 1 12 3565 5'" " " """ " 4256 691 ~-i/2 " " 13 4256 6 "' ' Globe ST3G " 4841 585 9 " " . 13 ·4841 7 " ' ';' " " 5457 .'616 10 '" '" 14 5457 8 " HTC OSCIG " 5712 255 8 " " 15 5712 ~' "~ Globe ST3G :' 5910 198 5-1/] " " 16 '59i0 10 " Globe ST3G '" 5964 . 54 2 " " Good for ~R '" 16 ' ' ' ~01 HO2 '17"' I Smith .Conv - ' 3221 262 ~20-1/~- " '~ .... 7 18 ' '3221 HO3 " -~ '~ " - 4563 1'342 14 ' ' · " 19 4563 HO4 " " " 5439 876 11-1/2 20 5439 HO5 " " "" .... - 5829 390 10 - - - 20 . . 5829 HO6 ' "'" "; .... '; .... - 5964 ,i35 4-1/2 " '- ' '" ....... _ 22 .. 5964 10Ri;'12-.1/4'' . 'Globe ST3G 3,1.4 6277 313 9-1/2 ' 112 350 T-3 B-6 .... _ 23 6277 11 .." Reed YT1AG 3-15 6731 454 10 -. i, " "T24 .... B-2 24 6731! 12 . " "' " " " " 7135 404 1i '" " '; 'T-4 B-3 . 24 71351 13 .. " Sec: S...4TG " ... 7.4.19 284 8 .... " ;, T_8 B-2 .... 25. 7419 14 " Smith DGH " 7808 389 9 i08' 3~1 "T-8 B-3 25 7808 15 " " " " " 8076 268 8 111 348 T-6 B-4 O.G. 1/8 26 8076 16' "" HTC oSCIG " 8266 190 9-1/.2 " "' T-6. B-3 26 8266 17 '- " Smith DGH' "'~' 8524 258 8-1/2 ~' ~" T-7 B-2 · 27 8524 18 ,, Globe..S.T3G 3-14 ' 8742 2..18 9. 102 369 .. 28 .8742 !9 " .... , Globe ST3G " 9009 267 9 " " 29 ...9009 20 . , . ! ..." " [ " 9190 181 7-1/2 " "' - .. 29 9190 21 " I Reed YT-i~G '" "' 9428 238' 10-'~/'2 " " 30. '-,. 9..42822 ,, ... " ,,.. 1-15,271~i 9666 238 '- il ,, ,, T_6 B-4 ...... 31 . . 9666 23 " " "'~ " 9795' 129 6 ,, .... i', 'T-4 .B-4 '" .2/1/69 9?95 24 "" . ..Globe ' ST3 3-i4 9'956 161 10-1/2 " .... 380 '" T-5 B-4 ..... .... 2 .... 9956 .25 , ,," HTC OSC'3A '"'" LosT IN"'HOI.E .......... 3 ... 9481 26 " Re~d 'YTiAG 3-15 9'700 219 3-1/2 " 323' 'T'I B-1 " " ST1AC ~Z~.~ LOST IN HOI,E 5 ,9700 27 '" ................. _ .q 9147 26R, " "" YT1AG 3-15 POLI.~;H '~'FF CEMENT PLUG ' . 10. ' ! 9339 28 " ' ' "' ST1AG 3-24 9410 71 7 102 - Dbrld; sidetracking 1! · I 9410 26R, "' ": " YTi'~G 3-i5 9512 102 " 10 " 321 _ 12 9512 29 " HTC 'oSC3A '" 9581 " 69 2 "' " 12 "' 9581 30 ",, .... Smith K2H ,, 9~05 124 6-1/2 ,, ,, T_6 B-4 1/2" 0.G 13 9705i 31 " " " " 9705 0 6 " ;' ~'-1 Bi1 Reamed 6 hrs _ 13 9705 32 " ,Globe M. T3G " .9722 1.7 1 98 305 T-1 B-1 ___ 14 t" 9722' 32'~:~ " " " " .... 9830 ' i08 6 ' 98 " T-5 B-2 14' I-. 9830!'33 ' " "'" i' S~3G "' 9942 i12 7 98 " TL4 B-1 _ 15 9942' 34 ~ '" 'Reed "'YT1AG " 10155 '213 '921/2 '" .... " T-4 B-2 . " 10312 157 9 " " " ';" 16 10155 35 " ' Smith DHG , _' 17 10312 36 ~" Reed "YTi'AG '" 10498 186 9-1/2 " '"' '"" "' _ 17 10498 37 " Reed ' "' " 10674 176 12 " " T-3 B-4 _ 18. 10674 ]8' '"' .... Globe ST3G " 10930 25'6 9-1/2 '"' '"~' T-6 B-6 _ 19 10930i'39 ,, ,, "i, " 11i15 185 9-1/2 " " Z-4 B-4"1/8" O.C. 2 _ 1111514.0' ." Smith DHG -" 11271 ' 157 9-1/'2 '"' "' ~-5' 'B-3 " '" 11 I Il I Ill, 2 ~ II ' ~45[7'[ 42 ' J G ~ Ob eMT3G" 11563 10g Jl21/2- _. 22t1!563!43l, II I l'llsr~liltlht K2H i ' Il ~664 I i 01 8 IIt IIi , TI5 B13 iL DN y - OIL CO. OF CALIi )RNIA DRILLING RECORD SHEET A PAGE: NO.., LEASE_Trading Bay Unit State WELL NO. G-16 FIELD LOCATION PERMIT NO., . 'SERIAL NO.' T;D. T.V.D. DEVIATION (B.H.L.) COMPANY ENGINEER SPUD DATE CONTRACTOR. TYPE UNIT COMP. DATE .. RIG NO. DRILL 'PIPE DESCRIPTION ELEVATIONS: 5VATER DEPTH 1{. T. TO OCEAN FLOOR R.T. TO MLLW R.T. TO DPJLL DECK R.T. TO PRODUCTION DECK APPROVED: BIT RECORD MUD' VEL. DEPTH & DEVIATION BlT ............. JET DEPTH .... ' VERTICAL [] ,DATE DEPTH ~O ..... SIZE MAKE TYPE .... SIZE OUT FEET .. HOURS ANN. JET' DI.R. ECTIONAL [] 2/23/69 11723 45 12-1/4" Globe ST3G ' 3-15 1189.2 169 9 98 -1305 T-5 B-3 24 11892 46' " Smit.h DGH..~ " 12086 194 11-1/2 " ". .." ' " ... 24 ,. 12086 47 " Reed .YT1AG ". 12258 172 ].2-1/2 ". " Rena{r RT ,· 26 ' ..12086 47 " " " " 12258 " " " " T-5 B-2 . . . . ..... 27 12258 CH1 7.-5/8" C. hris DIA - , 122.78. 19 -' - - Co~ g~mpl~ 28,, 1227.8 ~481 !2-.1/4" Reed YT1AG ,3.15 112403 125 7 98 205 T-_"4 3/1/69 124.,03 I49 " . ~ Glob~,., ST3G " 12498 95 g " " " .," ', , 3. 12421 50 '" ' Reed YT1AG " ]2421 0 4 - ,. ., 6 ...... 12421 51, .8-,1,/2" Smith DGH. _. .3.-13 12514 93 5-]/2 160 2~3 T-5 ...'B-.4 7 12514152 " " 3-12 12612 98 6 " 309 T-8 B-4 .. 8 ' 12612 53 HTC ' XDR ',,' .. ,, i2'736"' 124 ii1-1/2 ',, ,,' . .'T-4. B-2 · .. 8 ' 12736 .54 -' " -" "' " 12'834 98 12 " " T-6 B-2 9 12834 ~55 ........ " Reed YHG " 12878 44 7-1f2 .... ;' " ,, ,i' - 10 12878 56 " Globe PR{T3G " 12924 46 5-1/2 " " T-6 B-3 1./.8" o,g, ' "10 12924 57" ' "' Reed'' STi'A~' 3-11 12963 39 5 148 328 T-7 B-1 11 12063 ~58 " HTd '~R '" 13015' 52 5-1/2" " T-5 B-1 .... i2 ' ' 1'3015 59 " " X55R " LOST IN HOL~ · ~ ........ .,. . 15 12580 60 " 'u- ' ............ Reed YT1AG 3-12 12680 100 2 OK for ReRun 16 12680 61 ~" " ................... · ST1AG 3-3/4 12712 32 5 T-8 B-2 DDrlK _ - 16 12712' 60R~ " " " YTiAG 3-12 12810 ~ 8-iY2 ' ' T-4 ' B-6 . 17 12810 62 -' ',, ' ,, ,, ..... ,i' ".' 12875 65 [ 5-1/2 T-8 " ~'-4 ' 18 i2875 63J~~ "~' Smith sS-5. " 12'948 .~3'~ 8 .... . T-5 ' ~-8 .. ' ... !9 12948 64 " HTc 'x'55"R~ ..... 3-11 13'150 202 "' 18 20' 13150 '65~"' "" smiEh 'ss'5' " 13285 135' 15 140 328 T-~' 21. 13285 66. " H~C 'XSSR '"' 13'~46 1'61 26' '" .... "' - 22 i3~4-6 167 ,,' .... " ....... Smith S~-5 ": i-]625 179' 19 " " T'LJ B-4. - --2.3 . 13625 68 " Globe MT3C " 13661 36 ' Z~ " '" T-5" B-2 '174", o.g. , ,, -" 24' '.'...,!3661 69' '~ ' "H~C XDR ' "' ' stuc'.k-,whiie Teaming to bpt'tom, lo.s.t in hole. ... '26 70 '' ~' Reed" YT1AG ' - Clean out c~t & polished plug .... 4/28/69' 12040 171 " S~i'th DGH 3-1~ Drilled out cmt to 125~4' 29 - 12524 [72 " ' Reed ST1AG ~-12 12552 · 28 1 "' T-5 B-1 30 112552 73 " I :' " 3-24 12602 50 4 ' DDRL } T-8 ' B'24 ...... 30 12602' '74 "IHTC" ' XDR' jLil 1261'5 ~'13 '' 1/2' Pull_:d to recover surve'y "instrum ~11t'6~ 12615'~75 .... " " " '"' 1.2.~5]J~ 1140 .8__-i/2.,~'1_72 ,38Q .... i','T'-4 B-3 · - 2 ' 'i2755 ;76 "" ' '"" " .... " 12854 99 7-1/2 ' " " T-8 B-8 lost a cone 3 12854 ~74R~ " " " " 12868 "14 i-1/2 '"" " Drld on junk ' 3 ~;12968 77 "" · "" " ~'~'. i2899 3i '3-1/2 " " T-5 B-2 -4 12899 "78 ,,' · ,i " X55R " 13061 162 15 " " T-3 B-5 .... !. 5 13061 79" " " " " 13206 145 i'5-1/2 ~'" " T-8 B-8 'ioc['ed "' 6 13206' 80 " ' ' "'" '" ~ " ' 1~3'76 'i73 i6 " ' '" " T-6 B-8 ~ 7. 1337~ 81 ' '" ..... "- '" '" "' 135'0~ '1'28 i3 '148 '3~2 '" '~'" .... locked "'', [-_ 8 "13507 82' , " " " '" ''~ , 'i3632' 125 15 -" " T-7 B-8 ....... " 9 13632 83 "' ' " XDR ..... " '1368~ 52 9-1/2 '"' - '"'" T-6 B-6 . o . · . _ _ _ --. .. · ' - mUD rECOrD Page LEAS~rading Bay Unit State WELL NO. G-16 FIELD McArthur River TYPE DISTRIBUTOR ~ DEPTH WEIGHT I. ¥ISC. W.~. PH SALT OIL SAND SOLIDS REMARKS t ' /69 615 76 40 2 - Spudded mud lO 1574 77 '43 'I16~'8 8.7 6000 0 2 11 11 2480 77 42 10.2 9;3' 11000 0 '2 12 I12 3565 77' 43. 9.7 9.6 14000 0 2. 15 1'3 ' 4256] 81 39 9.8 9I,'2 14500' 0 3 16 " 14 5224 81 43 8.6 9.8 16000 0 2 ' 16 , 15 5712 81 39' 7.4 9.9. 17000 0 2 16 16' 5964 82 43 4.7 9.9 1900 O. 16 . Added .LCM, losing mud 17 2053 81. 38 5.1 9.3 18000 0 2 15 ' 18 3221 81 43 4.9 9.0 18000 0 2' 16 19 4563 80 41 ·4.8 9.4 18000 0 2 15 20 '' 5497 81 47 4.9 9.2 18000 0 LCM 16 , .21 ' 5964 81 41 4.8 9.5 18000 0 LCM 16 , 23 6120 75 41 8.4 9.0 18000 0 2 13 ., ! 24 6767 76 42 9.5 9.2 18000 0 2 14 25. 7135 75.5 41 8.5 8.8 18000 4-1/Z'l-I/~ 12 26 7990 75 52 5.8 8.8 18000 7 1-1/2 12 ' 27 8266 75 50 5.6 9.2 18000 7 1 11-1/2 ' 28 8700 76 45 , 5.6 9.8 18000 6.5 1 13.,5 , . ·29 9009 76.5 48 4.8. 9.8 18000 7.5 1 14 30 9397 77 65 4.8 9.6 18000 7 1 15 ,, 31 9666 79 58 5.4 10,0 17500 7.5 3/4 13.5 · ,~/1/.69 9868 80 62 5.2 10.5 17000 7.5 3/4 13.5 _ 2 10090 79 60 5.4 10.0 17000 7.5 3/4 13.5 ... 3 fishing 78+ 57 5.5 ' 9.5 1~000 7.0 3/4 13.0 4 9520 77 54 5.2 10.0 17000 7.0 3/4 13.0 , , , 5 9700 77 53 5.·3 9.5 17000 7.0 3/4 13.0 , 6 9724 76.5 54 5.1 9.6 17000 7.0 3/4 13.0 Fished 7 9724 77~ 51 5.4 - 9.4' 17000 7.0 3/4 14.0 ,, 8 9724' 77 68 8.0 10.0 17000 6.0 3/4 15.0 _ 9' 9724 77 68 8.0 i0.0 17000 6.0 3/~ 15.0 I0 9147 77 70 4.8 10.6 17000 6.0 3/4' 16.0 .11 9370 77.5 60 5, 10.8 17000 5 1 16 ' I ' 12 9560 77 75 4.8 10.6 17000 5 1 16 13 9581 78 . 63 4.6 !0.C 17000 4.6 1 16 14 9722 78 63 4.6 10,5 24000 7 1 17 Excessive torque , _ 15 9878 79 57 4.2 10.5 24000 8 1 16 16 10312 79 65 4.3 iO,C 26000 8 1 17 17 10580 79 63 , 4.2 I0.5 26000 9 1 17 18 10930 79 65 4.4 10.5! 25000 8 1 16' .. _ 19 - 79 67 4.2 10.5! 24500 7.5 1 16.5 · 20- 1111.5' 79 65 4.1 10,4! 24000 7 1 16 _ _ 21. - 79,5 68 4.0 10.41 26000 7.5 1 16 _ 22- 11563 78 65 3,9 10,51 25000 7 1 16 _ 23 11723 77,5 62 4 " 10,4[ 23500 7.5 1 ,16 , .. 2& 11,890 77 68 4.3 10,21 24500 7 1 16 25 1.2086 77 66 ,, 4.2 10,2! 25500 8 1 16 Shut down for rig repairs _ 26 ]~086 77 66 4,2 10,2 25500 8 .1 16 Rig Repairs - RT _ · 77 12141 78 67 4.2 10,2! 25000 8 1 16,5 2~ 12274 78 68 4 1. ].0.21 24500 8 1 16.5 _ .3/1/69 12400 79 68 4.0 , 10.2 24000 8 1 16.5 _ .2 l?Aqg 79 6]. 4.0 10.5i 24000 8 1 16,5 .. 3 17498 79 . 61 4.0 10.5 24000 8 1 16,5 - 4~ 1.2&21 79 65 4,0 10,5 24000 8 1 16.5 ... ., Set 9-5/8" csg. - 7 1 ~&61 7R 68 A 7 10.Ri 24500 7.5 1 16 8 ~7630 78 62 3,2 10,7i 24000 8 1 16 .. . 9 1750~ 77-5 55 2.8 !0.8! 24500 8 3/4 15,5 - !0I 12~7g 7R 54 2.6 10 25000 7.5 3/4 15,5 !! 12963 ,,78 - 58 2,8 11 25000 7 1 16 " 12 13086 78 56 2.8 I0.~ 24500 7 1 16 i 1.3 131~8i 78 54 2.8 10.5] 24000 7 3/4 16 Plugged back 1~ 12580 · 7~ ~4 2,8 10,51 24000 8 3/4 16 16 -12~80 78 49 3,0 10,8 24000 7 3/~ ],5 t.7 79 49 2,9 10.8 24500 8 1/2 15 ._ 18 129~o 78 50 3,0 i0,8 25000 8 1/2 15 19, ~ .77, &2 3,3, 10,S 26000 7,5 1/2 15 ' ' i UN ON OiL CO. OF CALIF~.ORNIA MUD RECORD ' SHEET B PAGE NO, LEASE Trading Bay Unit State TYPE WELL NO C--16 FIELD McAt thur Rt. ver DISTRIBUTOR r,^,~- [ r,~.~,~a w~.~da~'1 wsc. w.L ~a s~ o~n s~,~sonms ~a~s .. 3/22/6~ i3420 74 56 i.8 i0.2 25000 7.5 1/2 I II 23 I i~35 [58 74'5 58 1'5 110'2 25500 8 ]--/2 14 24 13661 74 55 1,O. .10,2 25500. 8 1/2 1.4,5 Stuck 25 13661 74' 55. 1,8 10;2 25500 8 1/2 14.5 Fished 26 13661 74 54 1,8 i 10,2 25000 8 1/2 14 " 27 : 13661 74 52 1,8 t0,2 24500 8 1/2 14 Pol~bod 4/29/6~ 12040 75 47 4,2 9,5 2.1000 7 1/2 12 30 12550 75,'5 65 3.8 1l 21000 7. 1,/2 13 . 5/1/69' '12600 75 5A 3.2 11 22000 7 1/2 lA ..2 12755 75.5 62 3.0 11 21500 a.5 3/4 14 ' 3 12854 75 60 2.6 11 . -24000 8 5 q/4 l.q,5 4 12920' 75 53 2.9 II 2~000 8 3/~ . ~5 13080 75 63 2.8 l 1 27500 ' 8 3/4 ] 3 6 13206 75.5 65 ?.5 ll - ?6g00 8 · 3/4 13 7 13379 75.5 55 2.5 ll 2550~ 8 3/4 8 13528 76 66 2.6 ll 25500 '8 !3/4 9 13684 76.5 62 ?.6 11 2~qfl g ~/A ]3- TD 10 } 13684 76 67 ~_6 11 76000 g 3/4 !4 ...... , ..... ...... , .... ., _ . . ~ ....... ,,. ,, ... ,, . , ,. . . ., , --- , ,, .. _ _ . ., ,, _ ,, , .,, ..... .... LEASE Trading Bay Unit State WELL NO. G-16 FIELD hcArthur River NO. ,- CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 17-3/4" .312 , , wall ~spiral wtd -- 601 Spira.1 Weld csg. 'i3-3/8"I 61# seallock" J-55' 5960 Cmtd w/.1850 sx B-J mix w/i/4# cello seal/.sx in 1st ' 1000 f t3 & 500sx CFR-2 preceded by 100 f tj'wtr. ,, 9-5/8" vario~a buttress various. 12416 Cmtd w/1000 sx w/1.% CFR-2 ~nixed w/fresh wtr & ' I oreceded w/ID0 ft3 wtr. .7." . ' 29# buttress N-80 & P-l]0 13663 ~mtd thru shoe w/300 sx CFR-2. Circ .... 8H thru DV~..colr... a 6171 Cmtd :hru DV w/100'O_ss_G', (;irc ?ERFORATING RECORD-.~ ' 75 ~*:~ C!P 7 a,~! 5/17/~9 DATE INTERVAL · E.T.D. REASON ~F~ ..... ~RESENT CONDITI0~ , , · 5/15/69 '12844-12884 13632 ' ' -- , 12904__12985 ". ,., 1300'5__13088 ,, , ,. 131~8_13142 " ..... 13172-13270 " ' , , , , , , , , , , INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE ~4CF GO~ REMARKS . 5/17/6(.t 1628 5.0 31.9 Il00 120 124 716 418 18 2031 5.2 31.5 1].25 1.20 124 1215 567 · 2. t- .' 20-47 4,1 31.8 1110 120 . 124 676 330 , . , · ,, · . . . . ., . , . ,, , ,. , , - -- , WELL HEAD ASSEMBLY TYPE: CASING HEAD: shaffer "}LD" w/2" S.E. outlets, 12" - 3000# CASING HANGER: Shaffer 12" nominal 9-5/8" Model KD - KS CASING SPOOL: Cameron 12" 900 x 12"900 w/2" flanged outlets TUBING HEAD:. Cameron DC-B12 12" 3000# x 10~' 5000# w/5000'# studded outlet TUBING HANGER: DC-FSB !0" nominal 4-1/2" buttress bottom x 4-1/2" EUE top TUBING HEAD TOP: Single string solid block log type w/master & swab valve, B~n flange to 5000# w/7" OD seal pocket MASTER VALVES: 4 1/~'~ CHRISTMAS TREE TOP CONN.: - · ~ EUE UNION OIL CO. Of CALIFORNIA DRILLiNg RECORD SHEET D PAGE NO., LEASE. Trading Bay Unit. State WELL NO. G- 16 , FIELD McAr, thur River DATE 1/6/69 10 11 12 13 14 15 E. T. D. 345 615 615 ED 601 top cmt 457' 979' 1788 3565' 4256' 4883' 5695 5910 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Moved rig from G-14 to Conductor ~48 well G-16. SPUDDED @ 10:00 pm 1/6/69. Made up d.a. & tagged fill in conductor.@ 345'. Drld 15" hole to 61'5. Opened 15'"hole to 22~" hole w/Servco Exp HO. .Reamed thru shoe of 26" Cond. w/Exp HO & 18" mill. POH. Ran 15 its 17-3,/4" csg (.312 wall) landed @ 601', w/Howco stab in float shoe on btm ofjtgl. Pumped 200 cu./t. Inlet wtr mixed w/4008caustic ahead of 650 sx of Class "G" cmt w/2% GaG12 .& Inlet wtr followed by 100 sx "G" cmt w/4% GaG12. Displaced cmtw/55 cu.ft, wtr. Had 100 cu.ft. cmt returns, to surface. CIP 9:30 pm 1/7/69. WOG & NU BOE on csg. 17-3/4" Casing' Detail Howco "Stab-In" Float Shoe 15 jts 17-3/4" csg (.312 wall, spiral weld) TOTAL Casing String Less csg above table Csg Landed (Rotary Table) 2.30 601.00 603.30 -2.30 601.00 Cut off 17-3/4" .csg. NU. Installed BOP (HYdrill). Unable to test. Mud pumped away @ 200~ @ 250 gpm. Pumped plug down w/Howco unit. Fnd hole in csg @ 514'. RIHw/dp to 514'. Spudded plug to 535'. Pulled up to 533'. Thru open end dp @ 533', pumped 200 sx 2%CaC12 - "G" cmt mixed w/Inlet wtr., followed by 100 sx "G" cmt w/6% gel, 1/2 cu. ft. perlite per sack cmt, 1% D-31 & 3% GaG12 mixed w/Inlet wtr. Pulled dp . to 120'. Closed Hydril & sqzd away 336' cu.ft, slurry thru hole, leaving 100 cu'.ft, slurry inside csg. and/or 60' cmt above hole. CIP@ 1830 hrs 1/18/69. WOO. Top cmt @ 456'. Drld out cmt. Displaced sdlt wtr w/mud. DDrld 615 to 874'. RI w/building hookup & continued drlg 12-1/4" hole to 979'. Drld 12-i/4" hole to 1574'. DDrld to 1765, turning hole to the left. Continued drlg 12-1/4" hole to 1788'. Drld & surveyed 12-1/4" hole to 3536'. Down 6 hfs repairing washed out mud line. Completed repairs on mud line. Drld to 3640'. Pulled off btm & circulated out gas cut mud, COntinued drlg & surveying to 4256'. At this point, it was necessary to cease drlg new hole due to condition of mud. Circulated & worked pipe while waiting on mud. Due to ice conditions, in Cook Inlet, supply boats have been unable to supply plat form with mud & chemicals First supply boat arrived w/mud lQ 2'00 am. Conditioned mud & hole. POH. For bit change @ 4256'. Had considerable amt of trip gas. Continued drlg 12-1/4" hole to 4883' w/trip for new bit @ 4841. Trip gas cut 81~F mud to 605 for 20 minutes. Drld & surveyed 12-1/4" hole to 5695', trip gas diminishing. Drld & surveyed to 5910. RU Schlum.berger & ran DIL. Due to hole taking fluid, ran d.a. in order to drill while adding LC M. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAge NO. 7 Trading Bay Unit State WELL NO. G-16 FIELD McArhtur River LEASE. DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1/16/69 17 18 19 20 21 22 23 24 25 26 5964' 5964' 5964' 5964' 5964' 5964' 6017 6731 7386 7808 8256 Drld to 5964' & added LGM. Opened 12-1,/4" hole to 17"- fm 601-1739'. Started rng very rough. POH, twisted off pin in DC leaving 2 steel DG's HO & stab in hole. PU overshot with 7-3/4" grapple. RIH w/same. Recovered fish. laid down 2 DC's , HO OK~. Reran HO. Opened hole to 3221. POH, RIH, with 12-1/4" bit to 5964'. Circ 4 hrs, condition mud & added LCM, no indication of gas. POH. RU Schlumberger and RIH to log. Unable to get logging tools below 3191', hung on shoulder. RD Schlumberger. RIHw/17" HO, f~3 opened ~le to 17" 3521' - 4563' and magna-fluxed entire B.H.A. · POH Found 3 jts HW worn, no cracks, and found crack in double box 6-5/8" by 6-5/8" sub. Opened 12-1/4" hole to 17" 4563' - 5439'. Trip for HO Opened 12-1/4" hole to 17" 5439' to 5964'. Made wiper run (15 stands) Circulated & conditioned hole f~r 13-3/8" csg. Ran & set 13-3/8" csg @ 5960'-, mixed & pumped 1850 sx B-J mix with 1/48 cello seal/~k in first 1000'ft3 & 500 sx CFR-2 preceded by 100 ft3 wtr. Displacedw/5090 ft3 mud. Bumped plugw/2000~ floats holding OK.' CtP @ 3' 15 pm (1-21-69). Crc A~proximately 950 ft3 cmt. WOC 8 hrs. 13-3/8" Casing Detail Bottom Top Length 5960.44 5958.44 2.00 5958.44 5919.22 39.22 5919.22 5917.22 2,00 5917.22 36.00 5881,22 36.00 -0- TOTAL No. Jts. Description - Howco shoe 1 13-3/8" 61~,J-55 seal lock csg. - Howco self fill diff collar 153 13-3/8" 61~J-55 seal lock csg. landed Below R.T. 5920· 44 154 its 13-3/8" casing Cut off csg. RI 9 its HW & I.d. same to be used on Rig 55. Welded Shaffer "KD" head, plate & gussets & drld, cmt & float collar. Tstd Hydril @ 1000~ OK., pipe rams @'1500~ OK. Drld cmt & shoe @ 5960, 1.d. pipe. Drld 12-1/4" hole to 6017'. D & S to 6277, chng bit & PU 12 jts HW. D & S to 6731. PO for new bit. D & S to 7386, .w/trip @ 7135'. D & S to 7808. D & S to 8076. PO for new bit. RIHw/bit & reamed 60' to btm. No drag thru dog leg. D & S to 8256'. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D Page NO.- 8 LEASE , TBU State WELL NO G-16 FIELD McArthur River DATE 1/27/69 thru 1/31/69 2/1/69 2/2/69 2/3/69 2/4/69 2/5/69 2/6/69 2/7/69 E. T. D. 9861 ' 10095 9481 ' 9700 ' 9700' 9733' 9733' 9733' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Drld & surveyed 12-1/4" hOle to-9861, made wipe trip ~ 9788 (15 std). · D & S to 10095'. Twisted off @ 1726', PU overshot, BS & hydraulic jars, RIH, latched on to fish @ 1726'. Unable to jar fish loose. Rigged up Dia Log & ran free point. Backed off @ 2033'. POH recovered overshot, 3 STDS. D.P. & 28' piece D.P. RIH, screwed into fish O 2033', circ. & pulled on fish, could not rotate, unable to work fish free, R.U. Dia"Log free point, found top steel D.C. only partially free, backed off @ 9909. Mixed & pumped 300 SX CFR-2 w/12% sand (36SX). Preceded C~ slurry w/50 ft.3 caustic water. CIP ~ 7:00 P.M. 2/2/69. .POH WOC 8 hrs. RIH - Found top cement plug @ 9481'. Polished off plug. Drld hard cement to 9550'-cmt soft WOC 4 Hrs. Drld hard cement to 9700'. Pulled up to 5900' & circ. WO inspected D.P. RIH to 9700'. Circ. 2 HRS. POH laying down all "E" drill pipe t'o be end area inspected by Tuboscope. Transferred same to G-17. RIH w/inspected grade "E" drill pipe received from G-17. Oriented & Dyna drilled from 97OO' to 9733'. DD not working properly. Started to POH. Pulled to 6418' where it stopped. Had free circ. & rotation, worked for 3~ HRS. drilling up w/slips & Kelly-came free- pulled to 6325' (1 stand), tight spot. Worked, pulled, rotated & circ. for lO HRS. Pipe parted while attempting to drill up w/slips, 'POH Found pipe twisted off ~ 1723' (approx. 2' below box end). PU overshot w/5" grapple, BS & hydraulic jars. RIH w/same. Found top fish 5127'. Latched on fish, circ. thru bit. Pulled 320,000#, overshot pulled off, recaught fish-same thing, POH. Picked up 7 3/8" overshot w/5" grapple RIH caught fish, pulled 350,00#. Overshot held. RU Dia Log. Unable to work more than 6 rounds of Torque into string, attempted, unsuccessfully, to back off 122' below top of fish (5200'). Unable to keep overshot on fish. POH. PU 9 5/8" overshot w/extension. RIH checked all breaks for tight. Caught fish. Backed off ~ 5802'. Chained out of hole. Laid down overshot & stub JT. of D.P. RIH w/~t. DP & bumper sub. screwed into fish. Ran free point & string shot. Top monel DC free but unable to run string shot to lower connection due to obstruction in drill collar. Fired string shot in top connection of top monel but did not get a back off. RIH w/another shot & attempted to back off bottom jt. of Hevi-wate, on third try backed off bumper sub @ 9623'. Left One Jt. of ~_~ X_~O ~ mon~ ~kijc~ sub..,. ~ ~.l~/_~" Bi_~t in Hole,. Chai-'ned out of h~-f~. Lai~down 20 its. "E" pipe & 6 jts. HW that were bent. RU Schlumberger ran collar locator log from 5967' to 5750'. Log stopped @ 5967'. Log indicated shoe joint in tact & in place. RIH w/l~" bit & tapered reamer. Drilled tight hole from 5967' to 6018'. Reamed to 6380' without touching anything. Pulled up 15' (6365') into keyseat. Top of reamer @ 6352'. Drilled one inch ¢ a time from 6352' to 6345'. Wiped out keyseat. Reamed to 6550'. No tight spots from 6352' to 6550'. Unable to find keyseat ¢'~418'. RIH to top of fish-lO ft. of fill on top of fish. LEASE. Tt~J State UNION OIL CO. OF CALifORNIA DRILLING RECORD SHEET D PAGE NO .... 9 VvqELL NO. G-16 FIELD. McArthur River DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 2/8/69 2/9/69 2/ o/69 2/11/69 2/12/69 2/13/69 . /2o/69 thru 2/23/69 a/24/69 2/27/69 9276' 9395 9512 9705 9722 9878 ll, ll5 ll, 348 to ll, 892 12,O86 12,086 12,108 12,258' 12,403 Broke circ. shale chute plugged. Los~ l~z hrs. unplugging same. Circ. hole clean. POH & picked up fishing tool. RIH w/1 jt. HW, BS, oil jars, & 30 jts. HWScrewed into fish. Unable to break circ. jared on fish for 2 hrs. Fish did not move. Unable to back off @ 9623'. Seven hours & 4. string shots later backed off ~ 9592' leaving i jt. HW & BS in hole on top of original fish. Qhained out of hole. RIH open ended. Circ. & conditioned mud in hole. Hung open ended drill pipe @ 9592' & cemented w/300 SKS. "G" w/l% CFR-2, w/17% sand added. CIP ~ 10:45 AM. 2/9/69. Theoretical top 9128'. PU Drlg. assembly. Ran into shoe of 133/8". Circ. & cond. mud. tagged top of cement @ 9147'. Cleaned out to 9276'. Cement soft. WOC 4 more hrs. With a total of 17 hrs on cement cleaned out to 9335'- Plug would hold 50,000# but still green. WOC 3 more hours. Drld firm cement to 9339'. RIH w/Dynadrill. Worked over tight spot at 6340'. Ran to bottom. Dyna- , drilled to 9395'- Continued Dynadrilling to 9410'. POH for drlg. assembly. No problems with keyseat ~ 5340'. Continued drlg. 12~" hole to 9512'. D & S 12~" hole from 9512 to 9705- Reamed 6 hrs getting to bottom @ 9705'. POH for NB, drld 9705' to 9722- Excessive torque. POH & changed DA. D & S to 9878'-Roller reamer apparently reduced torque. D & S 12~" hole 9878' to ll,ll5. D & S 12~" hole to 11,892. D & S 12~" hole from ll, 892 to 12,086. Ran to bottom. Rotary table shorted out. Pulled bit into 13 3/8" shoe. Repairing Rotary Table Motor. Completed'installing Rotary Motor. Reamed tight hole from 11,650' to 12,086'. Drilled 12,O86' to 12,104'. Due to hlle conditions made 32 Std. wiper run. While reaming at 12,074' the Kelly stripped in the drive bUshing. Pulled bit back into shoe of Casing. Changed out Kellys. Reamed 60' to bottom. Drld. 12~" hole to 12,211' circ 2~ hrs for samples' Drld. to 12,258. Circ. l~z hrs. POH & PU core barrel. RIH w/chris. DA core head & core barrel. Cored from 12,258' to 12,277'-core barrel jammed-POH recovered 19' core- 3' cong., 6' sand, 4' cong., 2' sand, l' shale, l~z' shale (all sand & cong.- cut flour & odor). On trip out w/core barrel hung in key seat @ 6447'. Drld. up 26'. RIH w/bit ~49 & worked over area 6300' to 6490'. Reamed core hole 12,258' to 12,276'. Drld. 12,276' to 12,403'. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. l0 LEASE TBU State . VVELL NO. G-16 FIELD McArthur River DATE E.T.D. 3/1/69 3/2/69 3/3/69 3/4/69 3/6/69 3/7/69 3/8/69 thru 3/11/69 3/12/69 3/13/69 3/14/69 12,498 12,421 12,421 12,421 12,450 12,612 13,048 13,123 13,128 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Started to POH pulled to 6447'-hung in keyseat. Drld. up (3~ hrs) now POH D&S 12~" hole to 12,498'. Circ. ~/2 hrs. POH strapped-out. Continued strapping-out, found 77' error (12,498'=12,421') no trouble w/key- seat area-RU Schlumberger. Ran DIL Sonic & Gamma Ray Density logs. Attempted to run LL-3 log. stopped @ 1620'. Unable to work through. R.D. Schlumberger. RIH & reamed, from 12,400' to 12,421'. Circ. 2 hrs. POH RU to run 9 5/8" CSG.. Ran 302 its. (12,395.37') 9 5/8 CSG. 'set ~ 12,416' (See below for details) 5/8" CSG. DETAIL _ BTM TOP 12416.07 12414.07 2.00 - 12414.07 12371.13 42.94 1 12371.13 12369.53 1.60 - 12369.53 12328.44 41.09 1 12328.44 12326.34 2.10 - 12326.34 10680.47 1645.87 40 10680.47 8503.32 2177.15 53 8503.32 6295.93 2207.39 54 6295.93 4009.43 2286.50 57 4009.43 53.82 3955.61 95 53.82 15.00 38.82 1 15.00 -O- 15.OO. landed Total ~2~16 ~ 0~ L362 j-ts Howco Float Shoe 47#, PllO, Butt. Howco Float Collar 47#, PllO, Butt. Howco Side fill Diff. Collar 47#, PllO, Butt. 47#, N80, Butt. 43.5#, N80, Butt. 40#, N80, Butt. 43.5#, N80, Butt. 47#, PllO, Butt. Below RT RU Haliburton & cemented 9 5/8" CSG w/lO00 SX w/l% CFR-2 mixed w/fresh water & preceded by 100 ft.3 water. Bumped plug w/2000#. CIP ~ 1:30 AM (3/4/69) Set slips in shaffer "KD" Head. RIH w/grade "E" DP and laid down same to be tuboscoped. Prepared to move rig to G-12. Rig released ~ 5 PM 3/4/69 for move to G-12 Moved rig back over G-16 @ 12:01 AM 3/6/69. PU & Rubbered a complete string of Tuboscoped drill pipe. Drilled out fill collar, float collar & shoe. Drilled 8~" hole to 12,450'. Drld & Surveyed 8?2" hole from 12,450' to 12,612'. Drld & Surveyed 8~" hole from 12,612' to 13,048'. Drld to 13,128'. Pipe parted 1731' below rotary, as bit was being pulled off bottom. Total recorded hook load @ this time was 365,000#. POH. Reco- vered 18 stands of "G" pipe plus a 29' stub of DP Pipe parted just above tool jt. on pin end. RIHw/overshot. Unable to catch fish. Changed over- shots. Caught fish but unable to back-off due to overshot releasing. Changed to 6 1/8" grapple. RIH Caught fish. Attempted to work left hand torque to 3,000' for back-off. Pipe broke, released overshot POH checked all joints. Ran back in hole. Recaught fish. Jarred on fish-no movement spotted free pipe & continued jarring-moving pull 5 bbls every 15 mins-no movement, circ. Pill out & rigged up dia log- ran free point. Backed off~ 12,825'-leaving 7 jts HW on top of D~ Mi×ed & pumped 100 s× CFR~ cmt w/~5~ sand .~- t /Inlet w~r (Theoretical top LEASE TBU State UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D ll PAGE NO. WELL NO.., G-16, FIELD McArthur River DATE 3/14/69 3/15/69 3/16/69 3/17/69 thru 3/23/69 3/24/69 3/25/69 ~/26/69 3/27/69 3/28/69 4/27/69 4/28/69 4/29/69 4/ 0/69 5/1/69 E. T. D. cont. 12,680 12,810 12,875 to 13,661 13,661 12,034 12,034 12,040 12,524 12,602 12,755 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS of plUg 12,560') POH & layed all "G" DP to be inspected. Pick up rental"~' DP from Reading & Bates-found top of firm cmt @ 12,580' drld cmt to 12,680'- circ. hole clean & POH picked up Dyna Drill, RIH & orient ed same. DD to 12,712, POH. picked up follow assembly & D&S 8~" hole from 12,712 to 12,810'. D & S to 13,661 While reaming to bottom w/new bit-stuck DP w/bit ~ 13,630' (31' off bottom). Work DP-in attempt to trip jars pull max of 470,000#. Pipe parted w/max pull of 380,000#. POH. Top fish ~ 1711'. Jt. parted in ~ody of "G" DP & · shows fluid washing indicating a washout. RI w/overshot-found top ~ 1742' (fish fell to bottom). Caught fish-work left hand torque down hole to trip jars & lower weight. Sub on top of overshot released. Screwed back into overshot-overshot released. POH-redress same. RI& caught fish. Backed off at 3024'-POH recover overshot & l' stub. RIH screw into fish. Jar w/460,000# without success. Ran free point. Unable to work below 12382'. RI w/1 5/8" sinker bars only-ran to 13650'. Pick up more weight to Run w/free point. Free point indicated free pipe to 12,700; partially free to 12,7OO' to 13,5OO'. No movement of pipe @ 13,507'. Attempted to back-off at 13,598', 13,482 & 12,998, without success. Backed off hevi-wate drill pipe at 12,658'. Chained out. Fish left in hole. 8~" bit, grant 3 point roller reamer ~13889, 6~"x24' monel ~052, 6}~"x18' monel(no number), 2-servco stabilizers ~10928 & #10819, X-O 4"IFx4~"IF (Wodeco), & 31 jts. Hevi-wate drill pipe. Ran open ended'drill pipe to 12,658'. Cemented w/lO5 sks. class "G" w/l% CFR-2 Mixed with 15% sand. CIP 2:15 P.M. POH. PU drlg assembly RIH to 11,907'. Circulated & WOC. Found top of cement at 12,531'. Drilled firm cement from 12,531' to 12,536' in order to check plug. Hole to be temporarily suspended. POH RIH w/open end- ed drill pipe to 12,534'. Mixed & pumped 200 sks class "G" cmt w/l% CFR-2 CIP 2:00 PM POH RIH Found top of .cement at 12,034. POH. Laid down BHA. Rig released 6:00 AM 3/28/69 Commenced moving rig from G-14. Completed rigging up. Test BOP's w/1500# ok. Laid down all used drill pipe & picked up new pipe. Commenced drlg cmt @ 12,O34'. Drilled out cement & conditioned mud. Dyna-drilled from 12,552' to 12,602' to sidetrack old hole. Reamed Dyna-drill run & drld 8~" hole to 12,615. Ran survey-wire line parted. POH. Rec~vered. instrument & wire line. Changed BHA drilled 8~" hole to 12,755'. .UNION OIL CO. OF. CALIFORNIA DRILLING RECORD SHEET D PAGE NO. 12 LEASE_ TBU State V~ELL NO. G-16 FIELD McArthur River DATE 5/2/69 5/3/69 5/4/69 515169 thru 5/8/69 5/9/69 5/10/69 5/11/69 5/12/69 5/13/69 5/1 /69 5/15/69 5/16/69' E. T. D. 12,854 12,899 13,O61 13,206 to 13,632 13,684TD 13,684 13,684 13,632 13,632 DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS Drld. & surveyed 8~2" hole to 12,854'. Lost one cone in h°le' Drld on ju~, recovered most of cone & bearings w/junk sub. continued drlg 8~2" hole to 12,899. Drld & surveyed 8~2" hole from 12,899 to 13,061 measured out of hole ~ %3,061'. No correction. D&S 8}~" hole from 13,206' to 13,632'. D&S ~/2 to 13,684 circ. ~/2hrs. POH & RU Schlumberger-logging- Completed running DIL, FDC, Sonic, & LL-3 logs change brake blocks & installing cameron casing spool. RIH & circ. for casing. POH & RU to run 7" casing. Ran 7" csg set ~ 13,663'. Cemented 1st stage thru shoe w/3OOsx CFR-2 CIP ~ lO:O0 PM (5/11/69) Opened "DV" collar & circ. 8 hrs. 7" CASING DETAIL 13~, 63.31 1-~,660.91 2.~O 13,660.91 13,617.04 43.87 1 13,617.04 13,615.34 1.70 13,615.34 11,345.41 2269.93 54 11,345.41 6,173.87 5171.54 125 6,173.87 6,171.66 2.21 6,171.66 36.00 6135.66 145 36.oo o Total Casing 13,621.00 325 jts. pe,s o Flip ~o_n_ Baker "G" Shoe 29#, P-110, Buttrest w/SC Baker float collar 29#, P-110, Butt w/SC 29#, N-80, Butt w/SC Howco "DV" Collar 29#; N-80, Butt w/SC CMTD thru "D~' collar ~/1000 SX class "G" neat, circ. approx. 75 ft~ Closed DV w/2800# ok CIP 2 7:00 AM (5/12/69) Nipple Down BOP & set slips installed seal & tested to 3500#. Nipple up BOP & Riser. Pick up 3~" DP RIH & drl out DV collar @ 6171'. Picked up 3~" DP & drld out to 13,626 POH & ran dresser Atlas CBL & Gamma correlation log & ran sperry sun directional gyro survey on dresser atlas line. RIH w/bit &.scraper & drld to 13,632' (equal to 13,645' Schlumberger measure- ment) mixed & spotted protecto mul pill on bottom. POH & layed down 3~" DP RU dresser atlas-perforating. Dresser atlas perforated hemlock zone, (see perforating record) w/~/z" carrier guns-4 holes/ft, rigged down dresser atlas. Rigged up & commenced running tubing Ran & landed 413 jts. 3~2 tubing & jewelry. See tubing detail. Nippled down BOE & riser. Installed & tested cameron tree. Tested tree w/5OOO#-ok. Dis- placed water & protecto-mul pill w/22,000 gals diesel. Set baker packer w/1950#. Held 1450# on tubing. Casing zero. Rigged down. Released rig at 1:30 PM 5/16/69. Move rig to G-14 for abandonment. Hemlock=95 da. + 16~ hrs.; "G"= 2 da. * 1 hr.; Total = 97 da. + 17Y~ hrs. UNION OIL CO. OF CALIFORNIA DRILLING RECORD Sh EET D PagE NO. f~ LEASE G-16 WELL NO FIELD, DATE E.T.D. 2 its. ~ jt. 57 its. 14 its. 14 jts. 13 its. 21 its. 17 jts. 32 its. 47 its. 56 its. 73 its. 58 its. 8 its. 413 its. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS TUBING DETAIL 3-1/2" Baker Shear Sub" 3-1/2" 9.20~ N-80 Butt. Tubing 3-1/2" Otis X-Nipple Baker Hydro-set Packer 3-1/2" Tubing 3--1/2" Otis X-0 Sleeve 3-1/2" Tubing Camco KBM Mandrel 3-1/2" Tub ing Camco KBM Mandrel 3-1/2" Tubing Camco KBM Mandrel 3-1/2" Tubing Camco KBM Mandrel 3-1/2" Tubing Camco KBM Mandrel 3-1/2" Tubing Camco KBM Mandrel 3-1/2" Tubing ' Camco KBM Mandrel 3-1/2" Tubmg Camco KBM Mandrel 3-i/2" Tubing Camco KBM Mandrel 3-1/2" Tubing Camco KBM Mandrel 3-1/2" Tubing Otis Ball Valve 3-1/2" Tubing' X-Over 4-1/2" Butt.X 3-1/2"Butt. 4-1/2" Tubing Hanger Landed Below Zero 1.20 61 1.70 7.25 31.53 3.70 1 770.03 7.00 436.55 7.00 435.73 7.00 404.60 7.00 650.76 7.00 529.14 7.00 983.57 7.00 1,41 8.22 7.00 1,71 9.07 7.00 2,256.45 7.00 1 , 749.93 4.35 235.00 .35 1.00 36.00 1 2,808. ll 12,806.91 12,744.93 12,743.23 12,735.98 12,704.45 12,700.75 10,930.72 10,923.72 10,487.17 10,480.17 10,044.44 10,037.44 9,632.84 9,625.84 8,975.08 8,968.08 8,438.94 8,431.94 7,448.37 7,441.37 6,023.15 6,016.15 4,297.08 4,290.08 2,033.63 2,0'26.63 276.70 272.35 37.35 37.00 36.00 0.0 Bottom 12,808.11 REPORT and PLAN of HI.B ~ TRM OKG KLV HWK REL FILE SUB-SURFACE SURVEY UNION OIL COMPANY TB.U.~ G-I 6 COOK INLET, ALASKA JOB NO.__ DATE MAY 1969 DRILLING CONTROL CORPORATION LONG BEACH, CALIFORNIA COMPANY Union Oil WELL. grayli[~g % 16 DRILLING CONTROL CORP. 8UP,,VEY DATA SHEET DATE May 1969 F I E L. D.,Cook ~let COUNTY__ SHEET NO. JOB NO. STATE, Alaska ~AS~ DE~H 61.5 658 75O 780 810 DRIFT ANGLE 2° 30~ 7© 45' ].0© 30' ll© ].5" TRUE VERTICAL DEPTH 615 657 749 778 808 843 873 979 i105 1293 1574 ~ 648 1.680 1713 174.5 2298 2605 2921 3424 4020 4256 4841 5412 ~7i2 ].2 ~'00~ I..5 °45' .21~ 30" 2! ° 3].° 30' 42 © 00' 44 © !!~ ° 30' 46° 00: 44© 17' :{7° 0O, 49© 30' 48© 45~ ,'1~° :,,0' 42° ! ~ 4O© 1_5~ ~ aO© O0~ 44 ~ O0 ~ 840 869 967 1082 1242 145]_ 1504 1526 1549 15.71 1713154 19551 65 2160108 2368}42 2717! 85 3i39t01 33391 13 37~7{ 24 4197i96 4401i60 t DEVIATION COU':&~E 259 64 229t 05 2371 57 3611 81 4OO 75 152 48 376 04 396 67 220 29 DRIFT Dm~--~ON ASS~D~I~ S 70© E S 50° E S 35° E S 81° E N 82© E S 82© E ~T N 89° E N 89° E S 88© E N 87© E N 83© E N 79© E N 75© E N 68© E N 69° E N 71° E N 71© E N 72© E N 76© E N 79© E N 84° E N 86° E N 88© E RECTANGULAR COORDINATES NOBTH 1, TO TPIS 49 65 142 70 217 28 294 64 406 44 503 138 532 47 57176 599 !45 607 i~ SOUTH EAST WEST 8 13 14 13 14 14 13 1i 18 15 12 8 2 2O 26 225 35 42.3 26 464 ~9 66]. 0~ 903 40 112~ o5 1344 67 168~ 78! 2077 63 2227 30 2601 27~ 2996 99~ 3217 15, DRILLING CONTROL CORP. 8,EET NO. 2 SURVEY DATA SHEET , COMPANY Union Oil 'Company - DATE May 1969 _ Joe No. WELL Graylin~ #16 FIELD- _ Cook Inlet ,,' COUNTY, 8TATE----~aska MEASURED DRIFT 'TRUE DEVIATION DRIFT RECT~GULAB COORDINATES VERTICAL COU]:I~ DIRE. CT[ON .... .................. DEPTH ANGLE DEPTH NORTH SOUTH EAST WEST 5910 47° 30" 4535'37 14598 S 88° E 602 05 3363 04 6277 46° 30' 4788 01 266~22 S 88° E 592 76 3629'10 6731 46° 00' 5103 40 326 56 S 82° E 547 30 3952 49 7135 . 46© 45, 5380 22 294~27 S 79° E 491 15 4241 34 7419 47° 30' 5572 09 209:39 S 78° E 447 62 4446 14 , 7806 38° 15' 5876 00 239 59 S 72° E 373 59 4674 01 8076 36° 00' 6094 43 158 70 S 70° E 319 31 4823 14 8266 36° 00' 6248 14 111 68 S 69° E 279 29 4927 40 8524 37° 15' 6453 51 156 17 S 65° E 213 29 5068 93 8742 38° 15' 6624 71 134 '96 S 63° E 152 01 5189 18 9009 40° 00' 6829 23 171 63 S 61° E 68 80 6339 29 9190 40° 00' 6967 88 116 35 S 60° E 10 63 5440 05 9291~ 39° 45' 7045 53 64 58 S 58° E 23 60 5494 81 00' s 9533 39° 00' 7237 32 43 42 S 59° E 98 04 5622 20 9652 44° 00' 7322 192 82 66 S 58° E 14184 5692 30 9773 46° 30' 7406 22 87 77 S 60° E 185 71 5768 31 9894 45° 45' 7490 65 86 67 S 57° E 232 41 I 5841 00 10,107 45" 30~ 7639 93 151 93 S 57° E 315 66 5968 42 10,264 46° 15' 7748 50 113 41 S 56° E 379 08 I 6062 44 10,450 47° 00~ 7875 35 136 03 S 55° E 457 10 6173 87 i0,626 I 46° 45~ 7995 94 ' 128 ,19 S 54° E 532 45 6277 58 L1,067 48° 45~ 8285 88 139 09 S 53° E 732 43 6542 95 -- . ,. , , ....... DRILLINGBwgvEyCONTROLDATA 8KEE?CORP' . , s.~T No. 3 _ ~, ~_ ~., COMPANY _ Union O~,l,Cc~p,any~ - DAT~ May 1969 JOe NO,~ ' ~ ' ' ' STATE, C_ Alaska w~uu_~ray!lng #16 F~LO ~ Inle% cou#T¥_ - -- · ........ r ' ...................... '~' - " "' '" ...... ' . MEAS~ DRIFT TRUE DEVIATION DRIFT RECTANGULAR COORDINATES VERTICAL COURSE D~N ~ .... t.. DEPTH ANGLE DEPTH No~rH SOUTH~ EAST WEST. - J~ 11,223 48° ~0' 839026 115 93 $ 52° E 803 80 '6634 30 1~,409 47° 00, 8517,11 136 03 $ 49° E 893 04 6736 96 , ~1,616 46° 00~ 8660 90 148 90 $ 49° E 990 73 6849 34 ~ · t11,844 43° 00~ 8827 65 155 50 $ 49° E, ~092'75 6766 70 ~2,038 42° 00~ 897~ 82 129 81 $ 50° E ~176 ~9 7066 14 ,, · 12,2~0 42° 00' 9099 ~4 1~5 09 549° E 1251 70 7153 00 12,326 42° 30~ 9~85 16 78 37 S 49° E ~303 12 7212 15 ~2,514 42° 45~ 9323 20 127 61. S 47° E ~390 15 7305 48 12,552 44© 45' 9350 20 26 75 $ 45° E 1409 06 7324;39 i~ 12,615 45° 00~ 9394 75 44'55 S 50° E 1437 70 7358 52 12,755 48° 00' 9488 43 104 04 S 47° ~ ~508 66 7434 61 ~3,061 49° 00~ 9689 18 230 94 $ 43° E 1677 56 7592 11 ~3,206 50° 00' 9782 38 111 08 $ 42° E 1760 11 7666 44 ~\~ ~3,379 5~° 00' 989~ 25 134 45 $ 41° E 186~i 58 7754 65 13,507 49° 00' 9975 23 96 60 $ 38° E 1937 70 7814 12 ~3,632~ 48° 15' 10,058 47 73 35 $ 37° E 20~2 18 7870 25 13,684 48° ~5~ 10,093 10 38 79 $ 37° E 2043 16 7893i60 CLO~URE 8152 54 S 75° 29' E · ,. 12,612 12,878 13,015 13,128 COMPANY__ Union. Oil Ccmpany WELL Grayling # 16 DP. IFT ANC, L~ DRILI~NG CONTROL CORP. SUIt, VET DATA BHEET DATE-- FIELD- Cook Inlet COUNTY . 43° 00' 44° 15' 44° 15' VERTICAL COU~ D~N 939, 9587 9685 9766 S 44° E S 42° E S 42° E SHEET May 1969 JOB NO- klaska STATE RECTANGULAR COORDINATI~ SOUTH EAST 7354 6 7480 8 7544 5 7597 1 WEST DRILLING CONTROL CORP. s. EET NO. 8/Jll;VEY DATA COMPANY Union Oil ~p~y , DATE , ~y 1969 .... ;os No ..... W~LL Grayling ~ 16 FIELD C~k ~let ....... COUNTY STATE, ,~aska _ ~ ~T~G~R C~~A~ ~~ DR~ DEtAiN D~ D~ ANG~ VER~CAL CO~ D~~N ' ', , R~~ ~ D~ NO~ SOU~ ~ST ~T "]38~ ...... ' 12,680 43° 00' 9442 54 46 S 44° E ~ 1472 29 7386 48 12,741 43° 00" 9487 15 41.60 S 49° E 1499 58 7417 88 12,810 41° 00~ 9539 22 .45~.~27 S 48° E 1529 87 .~ .'7451 52 12,948 40° 30' 9644 16 89 62 S 42° E 1596 47 7511 49 13,150 44° 00' 9789 47 140 32 S 43° E 1699 09 7607 19 13,285 47° 30' 9880 67 99 53 ' S 42° E 1773 05 7673 79 13,446 47° 15~ 9989 96 118 22 S 41° E 1862 27 7751 35 13,625 49° 30' 10,106 21 136 1~ ~ S 40° E 1966 53 7838 84 13,661 48° 45' 10,129 95 27 97 S 41° E 1986 96 7856 60 SPEI R Y. $UN DIRECTIONAL SURVEY REPORT FOR UNION OIL COMPANY OF CALIFORNIA TYPE OF SURVEY:, SUrwel g,~T°sc°pic Multishot SURVEY DEPTH: FROM,Su~face LEASF' Trading Bay '- ~ " FIELD: Mc Arthur River .. . COU.TY/P^RISH Kenai i~'- ' ~' '~ ~ ' OFFICE Anchorage, Alaska { ~ ., . . . FT. TO I3,67Q..~: .-~7:.~ FT. STATE. Alaska Jos No..SU.-3-16h5~ BAY NO~-I6 05-13-69 ' SURVEY DATE TRADING ............ MC. AP, T, H UR-=R.I-VER .......... ~': ............................................................................................................... V ER.T I C A L...- $ E C.T.! ON_CO MP,UT.E D_.A L ONG..,..C LO S U.R E.: ................... -~. ALASKA SPERRY-SUN WELL SURVEYING COMPANY SU-3-16454. RECORD OF SURVEY TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR COORDINATES '..MEASURED ....... ,-ViE,R.T,.ICAL SEVER I TY ...... -VERTI CA[ DEPTH DEPTH DEC MIN DEC DEC/lO0 SECTION NORTH SOUTH EAST 'WEST O, 0,00 ORIGIN AT THE SURFACE 0.00 0,00 200o .... 1.99,.99' 0 .... 15 N-..-.42 ...... W .................. 0,.00 .......................... -0.,.69 ............ ] .......... 0,64 ......................................................... , 400. - 399.99 0 30 N 88 W 0.I8 -2.42 0.70 -2.32 600, 599.99 0 0 S 0 E 0.24 -2.42 0,70 -2,32 80.0 ............. 1.7~94., 46 .... '- ...... 1-3--30 ........... S .... 80--E .................. 6, 7 5' ..........44,..26 .......................................................... ~ 7., ,.3 1000. . 980.22 21 45 N 88 E 4.48 116.50 -4.81 117.71 1200.. II55.98 28 30 N 89 E 3.38 209.89 -3.I4 213.i3 '1.4.0.0.., __ 1.31.7,,.7_9. 36 ..... 0 S 88....E ................ 3,83 .............. 326., 03 ............................................ ,7.,,.2.4_ 1600. 1462.26 43 45 N 85 E 4.47 459.05 4.80 468.39" 1800. 1607.34 2000. ........... 174.9.99 2200. 1887.66 2400. 2020.83 43 30 N 74 E 3,79 581.83 42.75 600,73 44--,30 N.-.73.-E ............ 0.60 .......... 705,73 ...............83,73 ....................... 734.79 46 30 N 72 E 1.06 832.75 128.56 872.76 48 15 N 72 E 0.87 963.39 174.67c~ 1014.67 2600° ........ 2152...05 ....... 49 0- 2800. 2283.26 49 0 3000.- 2416.43 '48 15 3200., ..... 3400. 2692.38 45 30 3600. 2837.45 43 30 ................. 3800 ...... 2983.72 ......... 43 ..... 0 4000. 3132.93 41 45 N..72-E ............. 0.37 ...... 1095.55 N 74 E 0.75 1230.I7 221.32 ........................1158.22 262.92 1303.32 N 73 E 0.53 1362.05 306.55 1446.01 N-~i-E ............ 0.89 ........ 1489.38 ......... 354.36~ .................... 1584.87J~-,. N 73 E 1.13 1615.46 396.07 1721.29 N 75 E 1.22 1739.32 431.70 1854.27' N._7.4- E .................... 0.42 .........1860,.97:~ ........... 469.30 ..................... 1985.39 N 76 E. 0.91 1981,77 501.51 2114.61 ..................................................................................................................................................................................................4200. 3286.70 39 45 N 79 E 1.39 2100.44 525.92 c.-- 2~40,'-14- -4-40 O. ..... 344.1 .. ,0.3 ......... -2, .9_.--30 ,N_.7-8 -. E 0...3.4L .....2,2.L 7...64. ......... 5.52..37 .......................... 2364 . .58 4600, 3594.23 40 0 N 80 E 0.68 2337.74 574.69 2491.18 · ,UN,I LO i~ ,. D I,,L~..C, OM P-A N Y-.O F__ CAI.;t E.O R N,[ A .................. ; ......................................................... PA G E ........... IRADING BAY NOi~F-16 05-13-69 SURVEY DATE i----MCARIHUR_..RI.,VER VER.T ICAL~_S.EC,II ON..C.OMPUIED.,.~ ALONG .CL,O.SURE._~ ALASKA, SPERRY-SUN WELL SURVEYING COMPANY SU-3-16454 .. " TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR COORDINATES ME A SUE ED-'-...VE RT-IC A L D E G M I N D E G D E G / 100 S E C T I O N N o'R'T 4800. 3749.I1 39 iS N 84 E 1.32 2458.83 587.92 2617.03 5000 ..... ;;.-390;1-.7~~.40 ....... 15 ............ N-8~__E · 0.49 ............ 2582.48 .................. 601 .,43 5200. 4050.39 42 0 N 85 E 0.93 2711.I9 613.09 5400. 4193.65 44 15 N 8~ E Z.17 2846.06 622.82 3018.08 5,600,,. ..... -4,33~0,.0.5 ........ 4.7 ......... 0 .........N ..... 88 ..... E ................... 1,,54, .......... 2988.65 .......... 627,.,93,_, ....................... 3164,26 ................. -- ........ .' 5800. 4~65.81 47 15 N 90 E 0.74 3132.87 627.93 3311.13 6600. 5020.26 45 45 S 85 E 1.07 3703.16 602.84 .................... 6800.. ........ 5159..20 .............. 46__ 0 .................. S..85_E ............... 0'12 ............. 3846.27 ............. 590.30 '7000, 5296.23 46 45 S 82 E 1,14 3991.76 570,03 7 ~0~ 5~-3-.27 46 45 5 77 E 1.82 4137.33 537 7400 ..... ----556~,,.67 ..... 4~ ..... 0_ S .... 77._E .................... O. 12 ........ ~283..50 .............. 504 7800. 5878.17 ' 35 30 S 75 E 3.87 4536.03 438 8000. .... 6041.A9 35__1.5 ............ S_73...E .................. 0.59 ....... 4650'.80 ............... 405 8200. 6203.81 35 45 S 72 E 0.38 4766.75 368 8400. 6365.61 ................ 8600. ....... 6524.81 ' · 8800. 6681.88 ......... ........... 3887.05 .............................. ....................................... 4174.63 °26 4316.57 · 35 ..................... 4459,09 · 88 4591.46~---" .o8 ................. .... · 97 4925.16 36 0 S 71 E 0.31 4883.14 330.70 5036.31 3.7 .... 15 ................. S.69..E ................. 0,86 ......... 5002,31 ....... 287,31 ............................ 5.149,33 ............................... 38 15 S 68 E 0.58 5123.81 2~0.93~ 5264,13 ~: UNI~ 0 N.- 0 I. L--C 0 MPA N Y-~O F-.-CA L.I~EO R, N I.A PA G E 'TRADING BAY NO (~-16 05-13-69 SURVEY DATE .MC AR-THUR--R-L..V, ER ............................................................................................................... VER. T I CA L_,-SECT.I ON-COMPUT, ED... ALONG,.,CLOSURE, ALASKA SPERRY-SUN WELL SURVEYING COMPANY SU-3-16454 RECORD OF SURVEY TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR COORDINATES :---ME'ASURED ...... -V.ERT. I CAL ............................................................................. SEVER I .T.Y ........... VER TI CAI,.- DEPTH DEPTH DEG MIN DEG,' DEG/IO0 SECTION NORTH SOUTH EAST WEST, " 9600. 7303.52 42 30 S 65 E 3.62 5610.38 26.67 5718.40 9 8 0.0-,,----7 4,4-1.,, 82 ............ .46.--1-5- ' .....S ..... 64-.-.E ......................... 1., 90 ......... 5749 , 85 .......................................... ?. 36 , 66 ....... 5848°2 5-~','~,.,~-,' 10000, 7583.24 45 0 S 62 E 0.94 5885.02 -103.05 5973.12 10200. 7721.54 46-15 S 62 E 0,62 6023,09 -170,88 6100.68 L,040.0 .......2.858°,5,8 ............... 46 ...45 ................ S .... 62 .... E ...................... 0.24' .............. 6162 ,.32 .................................... ~-239,2.7 ..6229,30 10600. 7994.98 47 0 S 61 E 0.38 6301,35 -310,18 6357.23 10800,~''' 8126,85 48 45 S 60 E 0.95 6443,43 -385,36 6487,45~-''~ L.LO00 .......... 82.58.,_0.6~__~9 ....... O. .S .... 58..~..E ................. 0.76- ......... 6584,24 ....................................... ~465,35.,.,6.~15',46 11200. 8392.53 ~7 ~5 S 58 E 0.62 6722.3~ -543,80 6741.01 11400. 8529,57 46 45 S 57 E 0.62 6857,31 -623.14 6863.18 .................. 11600, ....... 8669,1,3 ...... q5--.45 ......... S.--56 E ............... 0,61 .... 6989,08 ........................................ -703.25-.6981,95 11800. 8817,76 42 0 S 57 E 1,90 7113,06 ~--776.14 7094.18F-"' 12000, 8967,55 41 30 S 57 E 0,24 7235.84 -848,32 7205,33 [2200..~91.16..o.76 .... ~1-~5 ...... S-57...E 0,12 .... 7359.22 ............................. -920.85,.7317,02 12~00. 9264.80 42 15 S 56 E 0.41 ,7482.90 -996.04 7428.50 12600, 9407.45 44 30 1.2800-,------9541.,28-- ---~8 .... 0 13000. 9673.15 48 45 13200, 9801,71 50 0 .......... ~3400-. ......99.27,..57 ............... 5[ .... 0 13600. 10060.75 48 15 S 54 E 1.31 7609.84 -1078.44 7541.91 / -S--.53 .... E ' 1.78 ......... 7743.30 ............................ -1167.89.7660.61./,-'~"~- S 51 E 0.83 7875.93 -126~.52 7777,47 · S 50 E 0.73 8009.79 -1361.00 7894.84 5-49. E ................. 0,63 .........8144,25 .............................. -1.462,97._8012,.14 S 48 E 1,42 8272,00 -1562,81 8123.03 ~,~ --~-.~. ~.~.---TJ~LE-- C AL C U Lk,TJ ON,_P-RO C E D URE S..., A RE..B AS E,D,. ,.. 0 N-.IH E-...U S E-.,..O F-_IH E..IANG E NT.I A L-.O R.,. C HOR D .M E l HOD _e.~.~.~_. .HORiZONTA.L_-DI-SP-LACEMENT .,..= ...... 827,2 · O0 ........ FEET,. AT_. SOUTH ...... 79-._DEG o 6.._MIN,~ EAS.T(.TRUE) .............................................. STATE OF AI.ASKA suaMrr ~ ~UPLICA~ OIL AND OAS CONSERVATION CO/v~ITTEE MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS AP1 NUi%~ERICAL CODE 50-133-20162 6 LEASE DESIGNATION AND SEEIAL NO ADL 18730 WELL WELL OTHER 2, NAME OF OPERATOR Union 0il Company of California 3~ ADDRESS OF ~PF.,TtATOR ~ 507 W. Northern Lights .Blvd.~ Anchorage, A~aska 4. LOCATION C~F w~n~L Conductor 48, Leg 2, 1879'N & 1381'W from SE corner, Section 29, T9N, R13W, SM. 8. UNIT,FAP~ OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-16 (14-27) 10. FIELD A-ND POOL OR WILDCAT McArthur River - Hemlock I1. SEC., T.. R,, P,~.. ('BOTTOM HOLE OBJ~rrrvE) Sec. 29, T9N, R13W, SM. 1~, PERMIT NO. 68-109 ]3. REPORT TOTAL DEPTH AT END OF MONTi-L CHANGES IN HOLE SIZE, CASING AND CE1VIENTING JOBS INCLUDING DEPTH SET A_N-D VOL~TNIE~ USED PERFORATIONS. TESTS ~ RESULTS. FISHING JOB~. JLrNK IN HOLE A_ND SIDE-TRACKED HOLE AND A.N'Y OTHER SIGNIFICANT CI-LA. NGES IN HOL~ CONDITIONS. TRADING BAY UNIT STATE..G-16 (~4-27), APRIL 19.6.9 Rig Released from G-14 to G-16 @ 9:00 PM 4/27/69. Moved over G-16. Removed tree, installed BOE & riser. Picked up & RIH w/new Grade "E" dp & S-135 dp. Top cmt @ 12040'.. Circ& condition mud. Drld out cmt 12040'12523', bit torqued up. Believe to have sidetracked hole. PO, RI w/monel drill collars. Drld 12523- 12552'. Survey same as original hole. RIH w/DDrl, oriented & DDrld12552-12602', sidetracking hole. PO, RI w/follow assembly. Drld 8-I/2" hole to 12755'. Now Drilling. FILE ,,, 14. I hereby certify t~e ~or? ~orrec~ I' , - " ~¥1 NOTE--R~por% on this fa~ Js required for each calendar month, regardless of the sLat. us o~ operations, ana mus~ ~e filed in duplkate with the Divisio~ of Mines & IV~inerals by the 15th of the succeeding month, unless otherwise directed. l"orm No. P.--4 BEV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS WF, LL WELL OTHER 2. NAME OF OPERATOR Union 0il C~npany o£ C~t£orn~ 3, ADDRESS OF OPERATOR 4. LOCA~iON OF WELL SUBMIT IN DUPLICATE Page T~ ~5. AP1 NU~IERICAL ~ODE 50-133-20162 $. LEASE DESIGi~ATION AND SERIAL NO, ADL 18730 7. IF INDIAN, ALOTTEE OR TRIBE NAME 8. U~'IT,FARA~ OR LEASE NAME Trading Bay Unit WELL NO. S~ate C-16 (1~-27) 10. FIELD A_ND POOL, OR WILDCAT Ncirchur River - ll~lock 11. SEC. T., R., M.. (BO~I~OM HOI~E Sec., 27, TgN, R13L SM 12.~I~MIT NO. 68-109 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGF~ IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOL~ USED, PERFORATIONS, TESTS A_N-D RESULTS FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE A_N-D ANY OTHER SIGNIFICANT CHANGES IN HOLIi: CONDITIONS. . . .,CONTINUED RXH w/overshot, top of fish 1712'. F~sh had fallen to ben. In working le£t' hand torque doVe dp, sub on top of overshot backed off. Screwed back into Sub releasin~ overshot. ~R, redress~ overshot. RI ~ caught fish. ~k~ off ~ 3024' , recover~ 1' stub of pipe. Screw~ into fish 0 3024* &-']a~ without success. U~ble ~o ~ free poin~ below 12382'. hdc d~ r~ ~th 1-5/8" s~ker b~ ~o 13650'. ~n free po~0 indi=a~ pipe free co' Z2700-', ~rt~lZy free lZTOO'-13soo'. ~c~ o~f ~ 12658~. ~H, lay~ d~ ben~ dp. ~l v/o~p, h~s e 12658' ~Op o~ ~eh'. Cm~d 8-Z/2~ o~ hole w/lOS ~ Class "G" ~nd. ClPz 2:i5 p 3/26/69. al, f~ top fire =t ~ 12531'. ~ed plug tO 12536. Ci~c c~. RXH, plu~g~ across shoe of 9-5/8" cog w/200 Sx Class "G" w/1X C~-2~ CZPz 2~00 pm 3/27/69. ~H, ~ar~ top ~r a ~203~'. ~. now prep co ~ve rig fr~ 0-16 Co G-12 for re. irs' (I-16 TEHI~ORARZL¥ SUSPEIqDED 3/27/69. APR 17 1969 DIVISION OF OIL AND GAS ANCtiOI~,:GE '1.4. I hereby certify that ~, g in~ is~.r~4~D4~'(~ NOTE--Re~ort on this form is//equired~°r each Calendar month, regardless of the status of operations, and must ~ filed in duplicate with the Division of Mines & Minerals by the lSt~ of the succeeding moath, unless ot~e~ise directed. Form No. REV, 9-30-67 STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~ A~U N~:mc,~ CoD~' ' 50-133-20162 6. LEASE bl~SIGNATION AXD SEHIAL NO, 2, NAME OF OPERATOR Union 0il Company of California 3. A~DHESS OF OPERATOR 507 W. Northern Lights Blvd.s, Anchorage: Ak. 99_503 4. LOCATION OF WELL ADL 18730 1. ?, IF IND1AIq. AI2DTYEE OR TRIBE NAME WE~L WELL OTHER 8. ITNIT,FARA~ OR LEASE NAME Trading Bay Unit Conductor 48, Leg 2, 1879' North & 1381' West from SE corner Section 29, TgN, R13W, SM. , g. WELL NO, State G-16 (14-27) 10. FIELD A,ND POOL. OR WILDCAT McArhhur River - Hemlock 11, SEC., T., R.. M.. (BO~To~i' HOL~ Sec. 27, TgN, R13~. SH. ~. ~r ~o. ' ......... 68-109 ,, REPORT TOTAL DE~TH AT F-,~D OF MONTH, CI'L~NGF-S IN HOLE SIZE. CASING ~kND C~T'IN~ JOBs"I~CLUDING DEPTH SET ~ VOL~ USED, P~O~TIONS, ~TS ~ ~SULTS. FISHING JO~. J~K ~ HO~ ~D SIDE-~CKED HOLE BAY UNIT STATE.. fl-16 (14--..27) .. MAR_CH 1..9.6.9 POH w/core barrel, recovered 19' core. RI w/d.a. Open core hole 12258-12277. ~(~1~,,~. Drld 12-1/4' hole to 12403'. PO, hung in keyseat @ 6447'. Reamed keyseat area. ~ Drld to 12498'. Circ& condition for logs. RU Schlumberger~ ran DIL, Sonic, APR 17 I959 Ra¥--aEnsity Loss. Condit~on hole fo~ csg. ~n 302 its ~-5/8' 40~ 43.5t~ ~7t N-80 ~ P-~10 buttress v~o~o~o~[A~vOA~s~Ug~ hung ~/shoe ~ 123~0~. Cm~d ~/1000 sx Class .G. cm~ ~/1Z C~-2. CIP ~ A~ct-~O~,~.~o~1:~0 ~ 3/4/69. Landed csg~ ~stld Cbg head. Continued laying do~ Grade "E' dp. R~S Shu~ Do~ 4 hfs for Platfo~ produc~ion equi~ent e~ectrical ~ie in. ~e~ tempo~arily suspended 5~00 pm 3/~/69 for repairs on C-~2. Noved back to G-16 @ 12100 Midnight 3/5/69. Installed riser &BOE. Picked up rubbered & tuboscoped Grade "E' dp. Found top cmt @ 12075'. TSTD lydrill, blind rams & pipe rams OK. Drld out cmt, float collar & shoe. Drld 8-1/2" hole to 13128'. Picked up dp off btm. Worked dp while chansin$ mud pumps. ~hile moving pipe, dp parted @ 1730'. Hook lsad@ time of parting 365,000t. Drl$ lines Jumped crovn sheaves. Restrung Irl$ line~ POH. Recovered 18 stands dp + 25' stub. Ran overshot, unable to catch fish. PO, ran overshot w/extension, caught fish, grapple broke. PO, reran overshot, caught fish. Backed off fish @ 3011'. PO, recovered overshot. RI & screwed into fish. Jarred w/no success. Ran free point, fad pipe stU~k @ 12825. Backed off @ 12825'. Plugged across fish w/lO0 sx CFR-2, 15~ sand. Theoretical top cmt 12560'. CIP 2=00 am 3/14/69. Layed down all Grade "G" dp for inspection. RIH fnd top cmt plug @ 12580. Drld hard cmt 12580-12680'. DDrld 12680-12712' sidetracking original hole. Drld 8-1/2" hole 12712-13661'. PO, RIH, stuck pipe while reaming to btm @ 13630', 30' off btm. While attempting to work Jars w/380,000~, "G" dp parted. lV~rm No. P---4 ~A R~. ~-~o-~ STATF O~ ~EA SuB~= ~ ~~ [~. ~m N~C~ CO~ OIL AND GAS CONSERVATION CO~I~EE HLB ~ 50-133-20162 MONTHLY REPORT OF ~DRI. LLING OKG ~ [~' ~sz ~ss:~o~ AND WORKOVER OPERATIONS KLV _ . ~1 ~L ~8730 OTH[~ 2. ~ O~ OP~-~O~ ' ~ Union Oil Co~ of California -- ' ~~ss o~ o~vo~ ~ TradSng Bay 507 ~. Northern L~ghUs Blvd., Anchorage, Ak. 99503 S~aCe C-16 HcArChur R~ver - ~emlock Conduc~o~ 48, Leg 2, 1879~ North & 138~~ ~es~ ~rom SE -n.s~c..v..~.,~..~o~o~o~ corne~ Section 2~, TgN, R13~, SH. o~~ Sec. 2Y, TgN, Ri~, SH. - 68-109 l~. ~O~T TOTAL ~ AT ~D ON MO~'r~, C~N'G~ IN HOLN ~I~N, CASINO ~ OH~NG ~OBS INCLUDINO D~PTH SET ~ VOL~ USED, P~O~TIONS. ~TS ~ ~SULTS. FIS~NG JO~, J~K ~ HO~ ~D SIDE-~C~D HOLE A~ ~y O~ SIGHIFIC~T ~~ ~ HO~ ~ITIONS. T~ING BAY UNIT STATE G-16 (.14-27), February !969 Drld 12-1/4" hole to 10,095' twisted dp in two PO, top of fish 8 1726' ~ · . Ran overshot, worked over fish. Free circ, pipe stuck. Backed off dp below overshot ~ 2033'. PO & recovered dp stub & overshot. RI, screwed into fish 8 2033'. Ran free point, stuck ~ top of top drill collar. Backed off ~ 9909' leavinE 186' of fish in hole. PluEged across top of fish w/300 sx CFR-2 with 12% sand. POH. WOC 8 hrs. RI, found top cmt 8 9481'. Drld cmt pluE 9481' - 9700' hard cmt. ~ ~ PO & layed d&~ all Grade "E" dp for tuboscope end area inspectinE~ Picked up ~ inspected dp & RI w/DDrl. Orien~d & DDrld 9700' - 9733' ~ hole DDrldnot wor~nE properly. Star,id POH, pulied to 6418' ~ ~ . ~ stdetrackinE Ori~ ~ ~.~. - tight spot. o8 Worked DDrl free. Pulled to 6325' unable to work DDrldabove 6325' ' · Free rotation below, free circ. Worked Pipe. 'Drill pipe twisted~off @ 1723'. RI with 7-3/8" overshot. Worked over top of fish'@ 5079'. Attempted to. back off below overshot @ 5200'. OVershot released. P6H~ RI w/overshot w/e~tension caught fish. Backed off @ 5802'. PO, recovering overshotf RI & scrml~ed into fish @ 5802'. Free circ. Backed off fish below bumper sub @ 96~3~. PO, ran Schlumberger correlation log across shoe of 13-3/8" csg. Log indicated shoe & shoe Joint intact. RI w/tapered reamer. Drld tight spot 5967' - 6018' Reamed to 6380'. Pulled into keyseat @ 6352'. Reamed & drld up 6352' - 6345'' wiPing out keyseat. RI to top of fish Circ clean @ 9623'. PO, RI~w/jars, scrml~ed into fish @ 9623'. Jarred w/no success, unable to circ. Attempted backoff @ 9623' no good. Backed off @ 9592.'. Plug ~/300 sx "G" cmt 17% sand. CIP 10:45 am 2/9/69. WOC. Polished plug 9335/9339, hard cmt. PO & RI w/DDrl & keyseat wiper, tight hole @ 6340'. Wrkd keyseat wip~r thru section, hole free. Ran to btm. Oriented & DDrld 9339-9410 sidetracking orig hole. Drld to 12086'. Rotary Table DC motor shorted out. Replaced motor. RI w/da Drld out bridges 9550-9625. Reamed right hole 11650-12086. Drld to 12104. Made wiper run, tight hole on 'btm,. Re'Ceaed 11750-12074. Rereamed back to btm. Drld to 12258'. RI with 7-5/8" core barrel, cut core #1, Middle Kenai "G" sand, fm 12258'-12277' (19') Core barrel jammed. No~ POH w/core #1. ' 14. I hereby ~~~ sm~.~.~~ Dist. Drlg. Supt. OA~ 3/11/69 NOTE(/~epor! on t~:orm is required for each calendar month, regardless of the status of operations, and must be file~J in duplicate pot ! ~ with the Division of Min, Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. REV. STATE OF ALASKA svs~rr m ~CmLZCA~Z MONTHLY REP@ET OF ~DRILLING TRM AND WOR'KOVER OPERATIONS @KG vtg WELL 2.NAME OF OPERATOR ' Union Oil Company of California ------- _ 3, ADDRESS OF OPEP~TOR ...._. r 507 W. Northern Lights Blvd., Anchorage; Als ~g503 4. LOCATION O'F WELL Conductor 48, Leg 2, 1879' N and 1381' W from SE corner Section 29, TgN, R13W, SM. AP~ NU~ErU6,U, bODE 50-133-20162 6. LEASE DESIGNATION AND SE"RIAL NO. ADL 18730 7. IF INDIA]~, ALOTTEE OR TRIBE NAME 8.LrNIT,FA~ OR LEASE NA/~E Trading Bay Unit 9. WELL NO. State G-16 (14-27) 10. FIELD ~D POOL. OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M,, ~O~OM HOL~ oB,mc'rzv~ Sec. 27, T9N, R13W, SM. ]3. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING AND C]~{ENTING JOBS INCLUDING DEPTH SET AND VOLLrNEES USED, PERFOH&TIONS, TESTS AND RESULTS. FISHING JOB~, JUNK IN HOLE AND SIDE-TRACKED HOLE AND A_NY OTHZER SIGNIFICANT CI-IAN-~ES IN HOL~ COlXrDITIONS. T_RADING,-~ .BAY ~I..T STATE G-16 (14-27), JANUARY 196.9. SPUDDED @ 10:00 PM 1/6/69 Drld 15" hole to 615,. Opened hole to 22" to 615'. Ran 15 its 17-3/4" .312 wall spiral weld csg. w/HOwco stab in float shoe, hung @ 601. Cmtd w/650 sx Cla~--"G" w/2%'CaC12' followed by 100 sx Class "G" w/4% CaC12. Good returns to surface, tIP 9:.30 PM 1/7/69. WOt 4 hrs. Cut off csg. Install Hydril. P~essure tstd Hydril, could not build up any pressure above 200~. Fluid pUmped away @ 200# @ 240 gal. per min. Pumped Howco plug down csg tag plug W/sandltne @ 514'. RI w/o.e.d.p, to 514'. Spudded plug to 535'. Pulled up to 533" CloSed Hydril & sqz cmt csg leak w/200 sx Class "G" cmt w/6~ gel, 1/2 cu.ft, perlite Per sack, 1% D-31, 3% CaC12. CIP 6:30 PM 1/8/69. RI w/d.a. fnd hrd cmt @ 457', drld Out to 615'. Drld &-DDrld 12-1/4" h°le to 5964'. Ran Schlumberger DIL log, hole started taking fluid. RI w/d.a, added l~st circ. material. RI w/17" HO. Opened hole to 1752'. Twisted off drill collar. PO, ran overshot, recovered all fish. Reran 17" HO, opened hole to 5964'. Ran 154 its 13-3/8" 61# J-55 csg. Hung w/shoe @ 5960. Cmtd w/1850 sx 1:1 perlite followed by 500 sx CFR-2. Good returns to sUrface. GIP 3:15 PM 1/21/69. W0C 8 hrs. Cut off csg. Installed 12" S-900 Shaffer K-D csg head. Installed & tstd BOE. Drld out cmt & shoe @ 5960'. Drld 12-1/4" hole to 9692'. Now drilling. 14.1 hereby certify ~h' or~g ~,i~g~t,'~le ~ ' sm~ I~]; / ~ n~ Dist. Drlg. Supt. DA~ 2/6/69 NOTE--~eport ~n this for~ is required for each calendar month, regardless of the status of operations, anO must ~ file~ in duplicate with the DivisiOn of Mines & ~inerals by the 15th ~ the succeeding month, unless othe~ise directed. Union Oil Company of Califorr '~ 2805 Denali Street, Anchorage, Klaska 99503 Telephone (907) 277-1481 RECEIVe. · January 9, 1969 Director Division of Lands 344 Sixth Avenue Anchorage, Alaska 99501 WEST FORELAND AREA State of Alaska ADL 18730, WFore-5 Dear Sir: In accordance with the provisions of the captioned oil and gas lease, Trading Bay Unit State G-16, drilling from the Grayling Platform located on State Lease ADL 17594 was spudded on January 6, 1969. The proposed bottom hole location of said well is approximately 360' North and 2,200' East from SW corner Section 27, T9N, R13W, S.M. on said captioned lease. Very truly yours, Robert T. Anderson District-Land Ma.n.~er .;---'---h , ../' ,--" ,,-'~'¢/". //' i-ANC fRE'/. 8167) FORM SA ~'IB ~25.~M 8/67 MEMORANDUM TO.: I-- ,State of Alaska DIVISION ~ OiL AND m FROM: DATE : SUBJECTs At~ ~ ~ ippremld &pplt~ttom for pemlt to drf11, t locIUom ~on~ vel1. FORM SA?lB 125.5M 8/67 MEMORANDUM TO: [- FROM: State of Alaska ~~ OF' ImTURAL ~ES DIViSIOH OF OIL AND 64S DATE : ~ 20 l(ml~ SUBJECT~ Tre41ng ~ ~t e~16 ~mt O'11 ~ ~ (~jlifer~a, DIVISIOa ~ OIL AND GAS December* 2, 1968 Trading Bray Unit G-16 Unto~ Oil Coq~any of Caltfornfa, Operator Union Oil Company of Ctltfornta 2805 alt Street At--age, Alaska Sir: Enclosed is the app~ appltcatlon for permi t to drt 11 for ibhe above referen~ well. Well samples and core chips are not required. Enclosure O. K. Gilbreth, Jr. Acting Petroleum Supervisor Form P--1 REV. 9'30-67 RECEIVED SUBMIT IN TRIi ATE (Other instructior~. ~n reverse side) API 50-133-20162 6. LF~SE DESIGNATION AND SERIAL NO. ADL 18750 ~, IF INDIAN, ALLO'i'r~:~: OR TRIBE NA~E 8. UNIT~FARM OR LEASE NAME Trading Bay Unit 9. WELL NO, State G-16 (14-27) 10. FIELD AND POOL, OR WILDCAT McArthur River - Heml0ck 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 27: T9N, R13W~ S.M. 12. ,~,~o,,,,~; $100,000.00 OIL AND GA.~,r~I)I~r~'~t.T.4~,MMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACI( PLUG BACK [-] MULTIPLE ~_~ ZONE 11[. TYPE OF WORK DRILL IX] DEEPEN b. TYPE OF WELL OIL ~-~ OAS ['~ SINGLE[] WELL WELL OTHER ~ ZON. 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS O~F OPERATOR 2805 Denali Street, Anchorage, Alaska 99505 4. LOCATION OF WELL At surface Conductor #48, Leg #.2.~ 1879' North & 1581' West from SE corner Sec. 29, TgN' At proposed prod. ~o~e TOP HEMLOCK - 660 ' North & 660'.. East from SW coroner Sec. 27, 'r9N, ~1~-, 5.M. 13. DISTANCE IN MILES AND DIRECTION F.%OM NEAREST TOWN OR-POST OFFICE* 23 air miles NW of Kenai, Alaska ' ~ 14. BOND INFOR/VIATION: T¥~E Statewidesuret~a~dZorNo. Pacific Insurance Company B-55372. 15. DISTANCE FROM PROPOSED~' ' ~ ' "'-'~ -~* ;-~::" i.~16.-'~O;.OF A~ IN LE~E LOCATION TO NEAREST PROP~TY OR LEASE LINE/FT. (AI~ to nearest drig unit if any) '{8. DISTANCE FRO~ PROPOSED"~0'CA~d~ TO NEAREST WELL D~ILLING, C~PL~, : ' · - --~ I' - . ' ..-', - OR APPLI~ FOR, FT. ' .... ' J~ ' '~ ' 2;,400' : ~"' Jl4,6B, O'MD ~-tl,220'VD 21. ELEVATIONS (Show whether DF, RT, ~R, etc.) 99' RT above MSL 2~. : " '- ~OS~;CASI-NG AN~ CE~NG PROGR~ 17. 1~O. ACRES ASSIGNED TO THiS WELL 160 20. ROTARY OR CABLE TOOLS RO t ary 22: APPROX. DATE WORK WILL START* .January 1, 1969 SIZE OF HOLE SIZE OF C~SING 'WEtGH~'p~R'F0~i "GRAD~E ' SETTINg: DEPTH-" ' ': qUANTIT. 0F '22" ~ 17-3/4" " .312 Wall - Spiral Weld 600' 12'00 sacks' 17" 13-3/8, .... .-.61~ ;,.: J,SS. 5400' 3500 sacks 12%" 9-5/8"..40~,:43..5~.,:47~ N~P 12~200'. : . . 1200 sacks 8~,, 7,, Liner~ 29# ~ [. N-80 12~000'-14~60~,~: : -.: ~ 550. sacks .,. Cement 17-5/4" casing in ,22" hole,,at 600'. Install.20" Hydrill. Cement 13-3/8" casing in 17" hole at 5400'..~Insta}l BOE, Drill 1~'' +~. directional hole to 12,200'+. Run electric !ogs. Cement 9-5/8" casing at 12,200'. Drill 8½" directional hole to 14,600' TD+. Run electric logs. Cement 7'" Liner 12,000' - 14,600'. Drill stem test "G" sand and West Foreland. ' Isolate "G" Sandand west Fbreiand' Perforated intervals. Complete for production, in Hemlock Zone. TOP WEST FORELAND - 530'N & l180'E from SW corner Sec. 27, T9N, R13W, S.M. BOTTOM HOLE LOCATION - 360'N & 2200'E from SW corner Sec. 27, T9N, R13W, S.M. IN ABOVE SPACE DESCRIBE PROPOSED PROGR/klVI: If proposal is to deepen or plug back, give dat~ on present productive zorle and proposed new productive zofie. If proposal is to ~11, or deepen direct ¼onally, give pertinent data on subsurface locations and measure% and true vertical depths. Give blowout preven~l~/~ra.m. S,~N~;:[~~~~~~~-~X~ November 27, 1968 m~._~ Landman (This space for State office use) SA1ViPLES AND CORE CHIPS REQUIRED OTHER REQUn{EIVIENTS: [] YES ~ No DIRECTIONAL SURVEY 1~ YES [] NO g'g- f/*See In~l'ructi°ns O Reverse Side CONDITIONS OF APPROVAL, IF ANY: JA.P.I. NUAEERICAL CODE · K-5 -~ ~ '[. ' - (34-;~) ...... '~" . . · · . '-~ G--5 G'4 . ' ' ' ~ ' ' (32-~8) - . ~ - ] ''-- ~ , . :. G-IA~ . ~ .... ~-I~ ~ . ' .~. , . ~) . . . . . .. . ;'' .~, ' ' ~" D-I! ~ D.-! - ' , D-7 UNIoN~ MARA.~HON /.. ~G-12 ,,, ~ ........ '- ~, L.. ~_ · - ' - -~ I .... 1 . ' ~-6) ~ ~-z ...... ,,,. ALASKA DISTRICT ' ' WELL LOCATION MAP. , .' ~ :. .... D-~ UNION OIL CO. OPERATOR UNION TRADING BAY STATE UNIT 6-16 · : (14-27) · "-' ' :" '"' - - '" '" ~ ~ DATE NOV I, 1968 ' ' ~o~' zoo°,'" · sc,~ ~"= ~ooo' . ~.i' ,L "~"' ~,~)'~' ~t,~
