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Home My WebLink About169-047 rage ioii Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Wednesday, November 17, 2010 11:08 AM To: McMains, Stephen E (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: TBU G -30 (169 -047) Thanks Steve, it will be right now. La rry From: McMains, Stephen E (DOA) [ mailto :steve.mcmains @alaska.gov] Sent: Wednesday, November 17, 2010 8:58 AM To: Greenstein, Larry P Subject: RE: TBU G -30 (169 -047) The change has been made, injection volumes deleted on G -30 and added to G14A. From: Greenstein, Larry P [ mailto :Greensteinlp @chevron.com] Sent: Wednesday, November 17, 2010 7:58 AM To: Maunder, Thomas E (DOA) N f� Cc: McMains, Stephen E (DOA); Lambert, Steve A Subject: RE: TBU G -30 (169 -047) Tom, Looks like the AOGCC database got messed up. It had to be something simple and it turns out it is. No idea how this happened, but here is what is wrong. 1C , Attached are the Grayling hard copy scans of the 2005 months in question. The only well that is 50/50 Hemlock/West Foreland is G- 14ARD. The volumes attributed to G -30 rightfully belong to G- 14ARD. The hard copy scans attached show that we reported it that way, but somehow the AOGCC database got the volumes assigned to G -30 (a shut -in producer). Our OFM database has the volumes correctly entered, but the Chevron WPH database also has them incorrect. We'll be correcting that database also. Hope this helps. If you concur, have McMains give me a call to rectify. La rry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, November 16, 2010 10:12 AM To: Greenstein, Larry P Subject: TBU G -30 (169 -047) Larry, I happened to look at this well file while looking at production wells completed in multiple zones. This is probably not critical since the well, according to our record, has not produced since June, 2002. In the "production record" we have, it shows that — 500 mbbls of water was injected into the well in the 3 months September — November, 2005. Do your records show this? The record shows a 50 — 50 split between the Hemlock and W. Foreland pools. Any light you or your colleagues can shed on this will be appreciated. Tom Maunder, PE AOGCC 11/17/2010 August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com AUG 0 h 2009 02skp Oil & Gay Nns, Commissipp Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, Dale Haines SCANNED:, Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 1442 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Collapsed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform 1 ife Ba -28 1931190 Jun -03 No known dama a Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life DO 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life DiA 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 I no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe af� 911 OXAMIJ 11 uy1tu SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21 A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Mono od A-10 1670760 Apr -8 Collapsed casing Producin Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 iCollapsed casing Producing Coal Phase I Abandon abandon at end of platform life Mono od A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life ~HA OIL AND GAS CONSERYATION COPlPIISSION TONY KNOWLES, GOVERNOFI 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501 PHONE (907) 279-1433 FAX (907) 276- 7542 May 29, 2002 Chris Myers Dwight Johnson UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 Re: No-Flow Verification TBU Well G-30 (L), PTD 169-047 Gentlemen: On May 22, 2002 our inspector Jeff Jones witnessed a "no-flow test" on UNOCAL's Grayling Platform. The long string (L) of well G-30 was tested. The short string (S) on this well is shut in. Mr. Jones arrived on Grayling Platform and found the well isolated from the production system and "flowing" to an atmospheric vessel. Over the course of 3 hours, the well flowed 150 scf/hr at 3 psi with no liquid production. At the end of the observation period, the well was shut in for 3 hours for a pressure buildup. The wellhead pressure remained at 3 psi throughout the period. It has been concluded that the long string (L) of TBU well G-30 (169-047) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. As proscribed at 20 AAC 25.265 (A), the long string (L) is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any reason the well again becomes capable of unassiSted flow of hydrocarbons, the SSSV must be returned to'service. A copy of this letter should be maintained in the respective well file on board Grayling. Sincerely, Thomas E. Maunder, PE Sr. Petroleum Engineer TEM\jjc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor, Chair THRU: Tom Maunder, P. I. Supervisor DATE: May 22, 2002 FROM: Jeff Jones, SUBJECT: Petroleum Inspector No-Flow Test McArthur River Field Unocal/Grayling G-30 L / TBU May 22, 2002: I traveled to Unocal's Cook Inlet Platform Grayling to witness a No-Flow test on well G-30 L in the McArthur River Field. , On arrival I checked the status of well G-30 L (G-30 S is shut in) and found it open and flowing to an atmospheric vessel and blocked in to the production and gas lift systems. The initial indicated well flow was less than 180 SCFH of gas at 2 PSI and producing no crude oil. I monitored the flow and pressure for 3 hours taking readings every hour. 1 hour: 140 SCFH @ 2 PSI; no crude oil produced. 2 hours: 150 SCFH @ 3 PSI; no crude oil produced. 3 hours: 150 SCFH @ 3 PSI; no crude oil produced. The well was then blocked in allowed to build pressure for three hours. The wellhead pressure remained 3 PSI and bled to zero in 2 minutes 15 seconds. I spoke with Unocal representative Wayne Johnson regarding the test results, informing him that in my judgment well G-29 L qualifies for a no-flow determination under AOGCC guidelines (< 900 SCFH / 6.3 gals. flow in $ hrs). Summary: I witnessed a suCcessful No-Flow test on Unocal's Grayling Platform well G-30 L in the Trading Bay Unit. Attachments: none CC: NON-CONFIDENTIAL No-Flow TBU G-30 L 5-22-02 JJ.doc Unocal Nortt~ Ame Oil & Gas Division U -OCAL Ala~a Reg,an April 16, 1990 Alaska Oil & Gas Conservation Co~nission 3001 Porcupine Dr. A~chorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Regfonal Drilling Manager GSB/lew GRAYLING DISTANCE &.DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL 1804 LEG ~3: LAT = 60050' 22.569" LONG =151°36' 46.519" 2,502,352.30 212,272.70 1 2 3 4 5 6 7 8 9 l0 11 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 G-26 1806 2,502,358.05 212,269.49 G-25 1810 2,502,358.77 212,273.94' G-24 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 1798 2,502,350.83 212,270.89 G-23 & RD 1803 2,502,354.60 212,272.33 G- 33 1806 2,502,351.47 212,274.88 G-27 & 28 1803 LEG #4 :' LAT = 60°50' 22.832" LONG =151°36' 48.042" 13 14 15 16 17 18 19 20 21 22 23 24 LEG #1: LAT = 60o50' 23.575" LONG =151°36' 4Z. 505" ' LEG #2: LAT = 60°50' 23.313" LONG =151°36' 45.982" 2,502,380.80 212,197.90 1831 2,502,374.34 212,196.66 G- 14A 1825 2,502,376.65' 212,192.79 G-1 9 1827 2,502,380.90 212,191.32 G-13 1831 2,502,385.11. 212,192.92 G-15 1835 2,502,387.30 212,196.85 G- 5 1838 2,502,386.45 212,201.28 1837 2,502,382.96 212,204.12 G-3 1833 2,502,378.46 212,204.05 G-2 1829 2,502,375.05 212,201.11 G- 11 1 825 2,502,378.50 212,198.27 G-10 1829 2,502,381.63 212,195.72 G-17 & RD 1832 2,502,382.27 212,199.71 G-7 1832 2,502,455.60 212,226.40 1906 (Reserved for Compressors) 2,502,427. l'O 212,301.20 1880 37 38 39 40 41 42 43 44 45-- 46 47 48 2,502,421.45 212,297.82 G-12, RD & 2 1874 2,502,424.94 212,294.98 G-31 1878 2. 502,429.45 212,295.05 G-4 1882 2,502,432.85 212,297.99 G-1 18B6 2,502,433.57 212,302.44 G-9 1886 2,502,431.26 212,306.31 G-18 1884 2. 502,427. O0 212,307.78 G-14 1880 2_,_502,422.80 212,'306.18 G.-30 .......... 1876 2,502,420.60 .............2'12,'302.25 .................. G-8 & RD 1874 2,502,425.63 212,299.39 G-6 1879 2,502,429.40 212,300.83 G-32 1882 2,502,426.27 212,303.38 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 .]378 1382 1385 1383 1381 Unocal Oil & Gas I~ ,)n Unocal Corporation ~. RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL August 1, 1989 Craig K. White District Exploration Geologist- Alaska District Hr. Lonnie C. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Hr. Smith: As requested by the A.O.G.C.C. through A.O.G.A., we 'are providing replacement copies of reproducible (sepia) logs for Unocal-operated wells, as follows: Canoe Bay Unit #1 (Pure Oil Co.) Cannery Loop Unit #1 Cannery Loop Unit #2 Cannery Loop Unit #3 Clam Gulch Unit #1 Grayling 1-A Kasilof Unit #1 Kenai Unit 41-18 Knik Arm #1 Knik Arm St. #1 Kustatan #1 Kustatan #lA Ninilchik #1 Pittman #1 Pretty Creek Unit #2 (Chevron) Trading Bay Unit G-~O West Trading Bay St. #1 5" E-log 2" E-log 5" BHC, 5" Density~- 5" BHC c ~ ~QG~ 5" Density, 2" DIL 2" E-log 2" E-log Hudlog 2" E-log 2" E-log 2" E-log 2" E-log 2" Sonic .= 5" Hicrolog 5" CNL, 5" Neutron Ct. Rate GR-Neutron (tie in), CET log 2" & 5" Sonic, 5" Density 2" & 5" BHC, 2" & 5" E-log Please return one copy of this letter in acknowledgement of your receipt of this data. ~ ~ Craig K. White~ v~-~'- - ~ ?'"" ¢"" .~ STATE OF ALASKA ." ALASf '3IL AND GAS CONSERVATION COMo ..... SION APPLICA' FOR SUNDRY ROVALS 1. TyPe of Request: Abandon r-I Suspend 123 Operation Shutdown [] Re-enter suspended well ID Alter casing [] T~me extension ~] Change approved program [] Plugging ID Stimulate [] Puli tubing 12] Amend order [] Perforate ~ Other 2. Name of Operator Union Oil Company of California 3. Address P.O. Box 190247, Anchorage, Ak. 99519-0247 4. Location of wellatsurface 1876' N & 1378' W .~'SE Cr., Sec. 29, T9N, R13W, SM- 5. Datum elevation(DF orKB) 99' RT above MSL 6. Unit or Property name TradJ~g :Bay Unit 7. Well number G-30 At tOD of productive interval 2511' S & 2173' E f/Surface Location At effective depth 2848 ' S & 2286' E f/Surface Location At total depth 3377' S & 2414' E f/Surfac e Ix}cation 8. Permitnumber 69-47 9. APInumber 50--133-20187 10. Pool McArthur River Field feet 11. Present well condition summary Total depth:, measured true vertical 11,451 ' feet Plugs (measured) 10,329 ' feet Effective depth: measured 10,370 ' feet Junk (measured) true vertical 9397 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 365 ' 26" Driven 365 ' 365 ' Conductor 520' 17-3/4" 750 sx 520' 520' Surface 4779' 13-3/8" ' 2200 sx 4779' 4486' Intermediate '9866' 9-5/8" 1800 sx 9866' 8950 ' Production Liner 1659' 7" 1000 sx 9785'-11 444' ,8877' - 10,323' Pe,fforationdepth: measuredsee Attached '. true vertical '' ~ Tubing (size. grade and measured depth) LS 3-1/2", 9.2#, N-80 @ 10,058' /:":.~/~8 0il & GaS SS 2-7/8" 6 4# N-80 @ 9454' , · , Packers and SSSV (type and measured depth) Otis 9-5/8" R.D.Hi P~ ~ 9,444' ~is 7" Pe~ P~ ~ 9980' O~s 3-1/2". ~11 Valve NJDD1P ¢ 336' & 303' 12. Attachments Description summaryof proposal D Detailed operationsP~0gram ~ BOP sketch 13. Estimated date for commencing operation Subsequent Work ReP°rted on 14. if proposal was verbally approved Form No. , . - - Dated_J._/.__ Name of approver Mike Minder Date approved 1/3/88 Signed (~¢'~d_~ ~-2~'C, .Title Environmenta3 Enqineer - ~y~. ~ ', - ~ ~-~t-s ) Commissior~ Use Only /¢.,onditions of approval NoCfy commission so representative may witness I Approval [] Plug integrity [] BOP Test c't Location clearance NO. Dste 5/31/88 Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned Form 10-403 Rev 12-1-85 by order of ' the commission Date ~'".~ ~ SuUmit in triplicat~J. TBUS G-30 PERFORATION RECORD G-2 G-3 G-4 G-5 G-5 MD 9,588'-9.610' 9,660'-9,681' 9,702'-9,766' 8,824'-9,857' 9,878'-9,892' "G" ZONE TVD 8,701'-8,720' 8,765'-8,784' 8,802'-8,860' 8,912'-8,942' 8,96i'-8,973' HB-1 HB-3 HB-4 HB-5 HB-6 RLUG HEMLOCK BENCH 10,058'-10,088' 10,230'-10,280' 10,300'-10,390' 10,475'-10,535' 10,575'-10,585' 9,122'-9,149' 9,274'-9,318' 9,335'-9,414' 9,489'-9,541' 9,576'-9,584' AT 10,370' TMD DETAILED OPERATIONS PROGRAM 1. Rig up oYer G-3OL, Slot 44. Pull ball valve at 336' and clean out with coiled tubing to 10,370' ETD. 2. Run GR/CCL correlation log across Hemlock Zone. 3. Reperforate Hemlock Benches #1, 3, and 4 from 10,058'-10,088' and 10,230'-10,364' with thru tubing perf guns. 4. Return well to production. STATE OF ALASKA ALASK~A OIL AND GAS CONSERVATION COMMISSION REPOF( OF SUNDRY WELL {' ' ERATIONS 1. Operations performed: Operation shutdown ;D Stimulate .-!, Alter Casing E3 Other [] 2. Name of Operator UNTON OTT, CClV~ OF Cj~'r~-O~A 3. Address P.O. Box 190247, Anchorage, Ak. 99519-0247 Plugging ~ Perforate~ Pull tubing '-'- 5. Datum elevation (DF or KB) 99' RTabove ~L 6. Unit o6 Property n,-,me Prading Bay Unit Feet 4. Location of well at surface 1876' N & 1378' W f/SE cr. Sec 29, T9N, R13W, ~M At top of productive interval 2511' S & 2173' E f/Surface Location At effective depth 2848' S & 2286' E f/Surface Location At total depth 3377' S & 2414' E £/Surface Location 7. ~C_~.I~i~ u mbe r 8. Approval number Verbal 2F~/-/¢ ~' 9. APl number 50-- 133-20187 10. Pool McArthur River Field 11. Present well condit Total depth: Effective depth: ion summary measured 11,451 feet true vertical 10,329 feet measured 10,370 feet true vertical 9,397 feet Casing Length Size Structural 365' 26' 52'0.' Surface 4,779 ' · 13-3/8" I ntermed late 9,866 ' 9-5/8 "' Production Liner 1,659 ' 7" Perfora. tion depth: measured true vertical See Attached Plu~s (measured) Junk (measured) Cemented Measured depth ~ue. Verticaldepth Driven 365' 365' '7~6' ~ ............................. 5'2~" ....................... ~2~r ........... 2,200 sx 4,779' 4,486' 1,800 sx 9,866' 8,950' 1,000 sx 9785' -.11,444' 8877' - 10,323 12. Tubing (size, grade and measured depth) L$ 3-1/2", 9.2#, N-80 @ 10,058' SS 2-7/8", 6.4#, N-80 @ 9454' Packers and SSSV (type and measured depth) Otis 9-5/8" R.D.H. Pkr. @ Otis 7" perm packer @ 9,980' Otis 3-1/2" Ball Valve Nipple Stimulation orcem_n~o ' squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subseauent to operation Representative Daily Average Production or Injection Data 4. Attachments sS Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 85 - 13 7¢~.psi ll0 psi LS 234 - 208 790 psi 100 psi SS 135 43 15 1215 psi !10 psi LS 67 57 268 1215 ~s~ _m3_~ Daily Report of Well Operations ~ Co:Dies of Logs and Surveys Run ~ 15. I ,,..re~)y certify t,,,~t the foregoing is true and correct to the best of my knowledge S~igned ~~( . ~ l e Envirommental. Engineer ro~rn 10-~04 Re;', 12-1-85 RO~. Roberts /~ . - Dale 5/31/88 Submit in Duplicate TBUS G-30 PERFORATION RECORD G-2 G-3 G-4 G-5 G-5 9,588' - 9,610' 9,660' - 9,681' 9,702' - 9,766' 9,824' - 9,857' 9,878' - 9,892' "G" ZONE 8,701' - 8,720' 8,765' - 8,784' 8,802' - 8,860' 8,912' - 8,942' 8,961' - 8,973' HB-1 HB-3 & 4 10,058' - 10,088' 10,230' - 10,364' HEMLOCK BENCH 9,122' - 9,149' 9,274' - 9.392' CLL/sp 0505N ,~ION OIL CO. OF CALIFORNI PAGE NO LEASE TBUS WELL NO. G-30 FIELD McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 01/04/88 1/05/88 1/06/88 1/07/88 10,370' Continued to demobilize rigs. Rigged up wireline on G-30 long string. Pulled ball valve from 336'. Rigged up coiled tubing unit and tested equipment to 5000 psi. RIH and tagged fill at 10,362' DIL. Washed to ETD at 10,370' with 6% KCL with 1.5 PPB HEC at 1.75 BPM at 4000 psi. CBU at 2400 hours. Continue to CBU. POOH and changed jetting tool. RIH to ETD @ 10,370' DIL with no signs of fill. POOH washing each GLM. Rigged down C.T.U. Wait on boat to bring out Gearhart electric line unit. Received Gearhart unit @ 0530 hrs. RU same. RIH and tagged ETD @ 10,364' DIL correlated with GR/CCL. Begin reperforating HB 3 & 4 from 10,364' to 10,230' DIL with 2.50" O.D., 0° phasing, 16 gm, 4 spf through tubing guns. Continued to reperforate Hemlock benches 3 & 4 f/10,364' - 10,230'. Bench 1 f/10,058 - 10,088' with 2.50 "O.D., 0° phasing, 16 gm, 4 spf through tubing guns. Returned well to production @ 1200 hrs. RR and crews @ 1400 hrs, 1/7/88. STATE OF ALASKA ALAS~..~, OIL AND GAS CONSERVATION COMM!SSION APPLIC/:(. ,ON FOR SUNDRY A ..-'ROVALS 1. Type of Request: AbAndon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing r"l Amend order E3 Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) U.~_-:on Oil Cc~mpany of California 99' RT above .~L feet 3. Address 6. Unit or Property name P.O. Box 190247, Anchorage, Ak. 99519-0247 Trading Bay Unit 4. Location of well st surface 1876' N & 1378' W f/SE Cr., Sec. 2.9, T9N, ?~]3W, &~ 7. Well number G-30 At tod of productive interval 25!i' S & 2173 ' E f/S'~urface Location At effective depth 2848' S & 2286' E f/Surface Location At total depth 3377' S & 2414' E f/Surfac e Location 8. Permit number 69-47 9. APl number 50--133-20187 10. Pool McArthur P~ver Field 11. Present well condition summary Total depth: measured true vertical 11,451 ' feet 10,329 ' feet Plugs (measured) Effective depth: measured 10,370 ' true vertical 9397 feet Junk (measured) feet Casing Length Structural 365' Conductor 520 ' Surface 4779 ' Intermediate ' 9866' Production Liner 1659 ' Pe,doration depth: measured Size Cemented Measured depth True Vertical depth 26" Driven 365 ~ 365 ' 17-3/4" 750 sx 520' 520' 13-3/8" 2200 sx 4779 ' 4486 ' 9-5/8" 1800 sx 9866' 8950 ' 11 See Attached true vertical Tubin~ (size, grade and measured depth) !000 sx 9785'-11,444' 8877' - 10,323' 3-1/2", 9.2#, N-80 @ 10,058' SS 2-7/8" 6.4# N-80 @ 9454' Packers and SSSV (type and measured depth) Otis 9-5/8" R.D.H~ P~ 8 9,444' ~is 7" Pe~ P~ ~ 9980' O~s 3-1/2" ~!l Valve N~ppq~ ~ ~' ,~.A,,=~n,,,=n~s Description summs~of proposal D Detailed operations program date fo: commencing operation 14. If propc, sal was verbally approved Name of a.~prover Mike ~.4_nder z/3,/88 1...: :-.reh.,D, Cyertffy ~na~ the fore~o~o ~s Itu. an~ corre.t Id the ,..st of my knowledoe -/> . - '?;*' ' ' ' ~ -' '"- ) Commissio? Jse Only D~-',~ 5/31/88 ~Condi~ions of approval Approved by [] Plug integrity D BOP Test r--~ Location clearance "- ORIGINAL SIGNED BY LONNIE C. SMITH Approved COPy Returned., by order of the commission Form ~n ,,',c Rev 12-1-85 Submit in triplicate TBUS G-30 PERFORATION RECORD G-2 G-3 G-4 G-5 G-5 MD 9,588'-9.610' 9,660'-9,681' 9,702'-9,766' 8,824'-9,857' 9,878'-9,892' "G" ZONE TVD 8,701'-8,720' 8,765'-8,784' 8,802'-8,860' 8,912'-8,942' 8,961'-8,973' HB-1 HB-3 HB-4 HB-5 HB-6 HEMLOCK BENCH 10,058'-10,088' 10,230'-10,280' 10,300'-10,390' 10,475'-10,535' 10,575'-10,585' 9,122'-9,149' 9,274'-9,318' 9,335'-9,414' 9,489'-9,541' 9,576'-9,584' PLUG AT 10,370' TMD DETAILED OPERATIONS PROGRAM 1. Rig uo over G-3OL, Slot 44. Pull ball valve at 336' and clean out with coiled tubing to 10,370' ETD. 2. Run GR/CCL correlation log across Hemlock Zone. 3. Reperforate Hemlock Benches #i, 3, and 4 from 10,058'-10,088' and 10,230'-10,364' with thru tubing perf guns. 4. Return well to production. STATE OF ALASKA ALASN,-, OIL AND GAS CONSERVATION COMN,,oSION REPORT OF SUNDRY WELL OPERATIO 1. Operations performed: Operation shuldov,,n - qti~:..,~:.- 'i · . 2. Name of Operator 5. Un-ion O±1 Company of Ca]_±forn±a 3. Address 6. P.O. Box 190247, Anchorage, Alaska 99519-0247 4. Location of ,,',,ell at surface 7. Datum elevation (DF or KB) 99' RT above MSL Unit or Property name Trading Bay Unit Well number 1876' N & !378' W f/SE Cr., See 29, T9N, R13W, SM At tod of productive interval 2511' S & 2173' E f/ Surface Location At e~fective Oeptn 2S48' S & 2286' E f/ Surface Location At total depth 3377' S & 2a14' E f/ Surface Location G-30 8. Approval number 7-308 9. APl number 50-- 133-20187 10. Pool McArthur River Field Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 365' Conductor 520' Surface 4,779' intermediate 9,866' Production Liner 1,659 ' Perforation depth: measured true vertical 11,451 10,329 10,370 9,397 Size 26" 17-3/4" 13-3/8" 9-5/8" feet feet Plugs (measured) feet feet Junk (measured) Cemented Measured depth ~ue Verticaldepth Driven 365' 365' 750 sx 520' 520' 2,200 sx 4,779' 4,486' 1,800 sx 9,866' 8,950' 7" 1,000 sx 9785'-1'!,4¢4' See attached Tubing (size. grade and measured depth) LS 3-1/2": 9 2~; · . ,;, N-80 @ !0,058' SS 2-7/8", 6.4#, N-80 @ 9,454' Packers and SSSV(type and measured depth) Otis 9-5/8" R.D.H. Pkr. @9,444' Otis 7" perm packer @ 9,980' Otis 3-!/2" Ball Valve Yipple ~ 336' 12. Stimulation or cement squeeze summary · See attached Intervals treated (measured) Treatment description including volumes used and final pressure 8877'-10,323' & 303' 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl $$ 85 - 13 Prior to well operation LS 234 - 208 SS 135 43 15 Subsequent to ooeration L~ 67 57 268 14. Attachments Daily Report of Well Operations ~ Casing Pressure 790 psi 790 psi 1215 psi 1215 psi ~bing Pressure t10 psi 100 psi 110 psi 80 psi Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Date 4/22/88 Form 10-404 ¢r~v. i2-1-85 Roy D. P~berts \ Submit in Duplicate TBUS G-30 PERFORATION RECORD G-2 G-3 G-4 G-5 G-5 9,588' - 9,610' 9,660' - 9,681' .9,702' - 9,766' 9,824' - 9,857' 9,878' - 9,892' "G" ZONE 8,701' - 8,720' 8,765' - 8,784' 8,802' - 8,860' 8,912' - 8,942' 8,961' -.8,973' HB-1 i0,058' - 10,088' HB-3 & 4 10,230' - 10,364' HEMLOCK BENCH 9,122' - 9,149' 9,274' - 9.392' CLL/sp 0505N RECEIVED APR o Alaska Oi~ & Gas Cons. Commission TBUS G-30 CEMENT SUMMARY INTERVAL SQUEEZED "G" Zone VOLUME CEMENT cu. ft. FINAL PRESSURE psi G 2-3 G 4-5 9,588' - 9,681' 9,702' - 9,892' 3700 3600 HEMLOCK HB 1 HB3 HB 4-6 10,058' - 10,088' 10,230' - 10,280' 10,300' - 10,585' 80 123 71 3600 3700 3600 G5 & HB 1,3,4 9,824' - 10,390' 396 4400 CLL/sp 0505N TBUS G-30 STIMULATION SUMMARY Data Fractured HB-4 (10,320' - 10,340') as follows: 372 bbls of 3% KCL Fluid 400 bbls cross-linked gel w/radioactive tracer 90 bbls cross-linked gel w/o radioactive tracer Sand Fractured HB-4 as follows: 1125 bbls cross-linked gel 20 bbls 2 ppg slurry 20 bbls 4 ppg slurry 40 bbls 6 ppg slurry 100 bbls 7 ppg slurry displaced w/ 10 bbls.of gel and 162 bbls 3% KCL @ 300 psi. Data Fractured HB-1 (10,068'-10,078') as follows: 84 bbls of 3% KCL Fluid 290 bbls cross-linked gel Sand Fractured HB-1 asfollows: 670 bbls 30 bbls 30 bbls 30 bbls 40 bbls 70 bbls 8.4 ppg cross-linked gel 3 ppg slurry 4 ppg slurry 5 ppg slurry 6 ppg slurry 7 ppg slurry Displaced w/10 bbls of gel and 160 bbls 3% KCL @ 4400 psi CLL/sp 0505N .GRAYLING PLATFORM TRADING BAY UNIT G-30 17-3/4" C./I 0 520'MD / 13-3/8" C. 0 4779'MD / OTIS 9-5/8" DUAL PKR. 0 94.4.4.'MD 9-5/8" C. ~ 9866'MD Z OTIS 7" W.D. PERM PKR. {I, 9980'MD · 7" LINER F/ 9785'- 11444'MD SS: 2-7/8" 6.4.~ N-80 SEAL LOCK e 9454'MD IIGI' ZONE 9588'-9610' (22') 9660'-9681' (21') 9702'-9766' (64') 9824'-9857' (33') 9818'-9892' (1 I_S: 3-1/2" 9.2~ N-80 SEAL LOCK 0 10058'MD HEMLOCK BENCHES ~ oo5s'- ~ oo~s" (3o') 10230'- 10364' (1 ETD 10370' CMT PLUG UNION OI['F ,O. OF CALIFORNIA DRILLING RECORD PAGE N LEASE TBLIS G-30 McArthur River Field WELL NO,~FIELD DATE E.T.D. 1987 GRAYLING 10-02-87 10-03-87 10-04-87 10-05-87 10-06-87 10-07-87 10-08-87 10-09-87 10-10-87 10-11-87 10-12-87 10-13-87 ~30 HISTf 10,020~ 9,353 5,867 10,020 10,030 10,400 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Worked tubing stop out of hole (recovered several pieces of wire with ct). Fished and recovered prong. Latched onto SSSV and could not jar up or down. Ran prong and tubing stop back in SSSV. Released rig at 1200 hours, 102/87. Continued moving rig #54 from leg #3 to leg #2 at 2400 hours. Continued rigging up on leg #2 at 2400 hours. Moved rig over G-30. Rigging up slickline and ran a gauge cutter to ball valve at 300'. Retrieved ball valve from both long and short strings. RIH to shift sleeve in long string at 9395' at 2400 hours. Unable to open long string sleeve at 9395' or 9453'. Tripped for jet cutter. Cut long string at 9462'. Displaced tubing and rathole with 6% KCL and spotted a sized salt pill across perfs. Perfed long string at 9342'. Circulated well dead with 6% KCL. Installed BPV's 5nd removed tree. Nippled up riser at 2400 hours. Continued rigging up stack. Tested BOPE. Attempted to pull dual packer free without success. Cut long string with jet cutter at 9353'. Pulled and recovered tubing and production equipment from 9353'. Laid down production equipment at 2400 hours. Installed and tested 2-7/8" rams. Verified short string fish at 1270' with slickline run. Performed manual backoff on shortstring and recovered tubing and production equipment. Top of short string at 5867'. Installed and tested 5" rams. RIH with 3-1/2" grapple and overshot on 5" drill pipe. Engaged fish at 5867'. RIH with jet cutter at 2400 hours. Cut off 2-7/8" short string at 9283'. POOH and laid down production equipment and tubing. Found and recovered several thousand feet of slickline in tubing fish. RIH with overshot and tagged fish at 9285'. Could not mill over fish. Tripped for mill shoe and 12' extension at 2400 hours. Worked over short string fish from 9285' to 9297'. POOH and recovered a ball of wire. RIH with overshot and grapple. Engaged top of fish at 9285' and performed manual back. POOH and laid down tubing and pups. RIH and engaged fish at 9328'. Ran jet cutter, stopped at 9360'. Ran string shot to 9420' and performed controlled back-off at to, of dual packer. Rigged down wireline at 2400 hours. POOH and laid down fish. Changed to pipe rams to 3-1/2" X 5" variable and tested. RIH with overshot and engaged top of long string at 9365'. Jarred dual packer free and circulated bottoms up. POOH and laid down production equipment. RIH with overshot and engaged long string at 9476'. Jarred tubing and seals free from permanent packer. Circulated clean at 2400 hours. Laid down remainder of long string and seal assembly. RIH with 6" bit and scraper. Washed from 9972' - 10,028' (top of packer). CBU. Tripped for 6" mill shoe. Milled over packer from 10,028' - 30' and packer came loose. CBU and POOH at 2400 hours. Laid down packer seal bore and bottom slips. Ring nut left in hole. RIH with 6" burn over shoe and tagged junk at 10,058'. Pushed junk to 10,322'. Milled junk to 10,369', could not go any deeper. Circulated clear and POOH. Junk baskets were full of miscellaneous junk and wire. RIH with 6" flat bottom mill and cleaned out from 10,361' - 10,369'. Milled junk to 10,376' at 2400 hours. UNION 0 .;0. OF CALIFORNIA DRILLING RECORD PAGE NO, LEASE -- DATE 10-14-87 10-15-87 10-16-87 10-17-87 10-18-87 10-19-87 10-20-87 10-21-87 10-22-87 10-23-87 'J.'I:RJ~ E.T,D. 10.383' 10,384' 10,393 10,290' 10,182' 9,5121 WELL NO._,~FIELD, M~.L~lu~. Kiv=~ Fi=id DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Circulated and pumped hi-vis sweeps at 10,376'. Tripped for 6" burn over shoe. Worked junk from 10,375' - 10,376' and milled on junk at 10,376' without success. Pulled to 9500' and repaired brake water cooling pump. POOH. Boot baskets full of misc junk. RIH with 6" flat bottom mill. Milled and worked junk from 10,376' - 10,383'. Pumped sweeps at 2400 hours. Continued milling on junk at 10,383'. Tripped for new mill. Milled on junk with flat bottom mill at 10,383' without success. POOH and recovered small amounts of junk in the boot basket. Changed out brake blocks. Tested BOPE. RIH with 6" burn-over shoe at 2400 hours. Milled on junk with 6" burn-over shoe at 10,383' without success. RIH with 3" X 5-3/4" tapered mill. Milled on junk and made 1-2 inches. Tripped for burn-over shoe. Milled on junk at 10,383' at 2400 hours. Continued milling on junk at 10,383'. Tripped for new burn-over shoe. Milled on junk at 10,383' without success. Tripped for new burn-over shoe. Milled on junk at 2400 hours. Continued milling on junk at 10,383'. Tripped for new mill shoe with diamond cutters. Pumped hi-vis sweeps. Milled on junk to 10,384' at 2400 hours. POOH with mill shoe, indicated being over junk 14". RIH with overshot and 4-5/8".grapple. Worked over fish to 10,384'. POOH with no recovery. RIH with 6" impression block. Tagged fish at 10,383'. POOH. Impression block indicated two sinker.bars side-by-side. RIH with 4-3/4" X 3-1/2" ID box tap. Worked over fish at 10,384'. Kept pulling off with 8-10,0009 over-pull. Tripped for 3-5/8" X 2-5/8" box tap at 2400 hours. Continued RIH with 5-7/8" OD box tap with 2-5/8" ID. Worked over junk at 10,383'. Pulled off junk with 35,000# over-pull. POOH and recovered 2 pieces of wireline sinker bar (5,08' and 1.35'). RIH with burn over shoe and mill on junk from 10,384' - 10,386'. Pushed junk to 10,393'. Trip for combination overshot. Attempted to catch fish at 10,393' without success. Laid down fishing tools at 2400 hours. Performed weekly BOPE test. RIH with 6" bit .and 7" scraper to 10,393'. Pumped 30 barrel HI-VIS PILL. POOH. Ran wireline gauge ring and junk basket to 10,350'. Ran a GR-CCL strip from 10,350' - 9249'. RIH and set a cement retainer at 10,290' DIL. Tripped for drill pipe and stinger. Stabbed into retainer and obtained an injection rate of 1/2 BPM at 2850 psi at 2400 hours. With 7" retainer at 10,290' DIL, pump 10 bbl fresh water and 125 sacks (154 ft 3) of Class "G" cement with 10% 100 mesh sand and additives. Initial squeeze pressure of 2300 psi at 3/4 BPM. Final squeeze was 3600 psi at 0 BPM. Total of 58 sacks (71 ft3) below retainer. CIP at 0215 hours. Reversed out and POOH. Ran an 8-1/2" bit and 9-5/8" scraper to'TOL at 9785'. Circulated clean and POOH. Ran and set a cement retainer at 10,182' DIL. Tested surface cementing equipment ~ECFiv 4000 Psi. Cemented Bench ~ with 15 barrels of fresh water ahead followed by 100 sacks of Class "G" cement with 10% 100 mesh and additives. Initial squeeze pressure of 3000 psi at 3/4 BPM. Final squeeze pressure of 3700 psi at 0 BPM. Reversed out and POOH at 2400 hours. Continued to POOH with retainer stinger. Set retainer #3 on d~it~!~i~e at 10,000' DIL. Rigged up Howco and tested lines to 4000 psi. Cemented through retainer with 15 barrels of fresh water ahead followed by 150 sacks of Class "G" neat cement with additives followed by 5 barrels of fresh water. Initial squeeze pressure 2550 psi at 1 BPM, final pressure of 3600 psi locked up with 65 sacks below retainer. CIP at 0930 hours. ReVersed out and POOH. Set retainer #4 on wireline at 9691' DIL. RIH and stung into retainer. Tested surface lines to 4000 psi. Cemented through retainer with 15 barrels of fresh water ahead UNION O4 ;O. OF CALIFORNIA DRILLING RECORD PAGE NO, LEASE TB~S G-30 McArthur River Field WELL NO, FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10-24-87 10-25-87 10-26-87 10-27-87 10-28-87 10-29-87 10-30-87 10/31/87 11/01/87 9785' 10,000' 10,192 10,370 9813' 10,227 10,370 followed by 150 sacks of Class "G" cement with 10% 100 mesh sand and additives followed by 5 barrels of fresh water. Initial squeeze pressure 2300 psi at 1 BPM, final pressure 3700 psi locked up with 73 sacks below retainer. CIP at 2200 hours. Reversed out and POOH at 2400 hours. Continued to POOH with cement stinger. Set retainer ~5 on drill pipe at 9512' DIL. Stung into retainer. Tested surface line to 4000 psi. Cemented through retainer. Tested surface line to 4000 psi. Cemented through retainer with 125 sacks of Class "G" cement with 10% 100 mesh sand and additives. Initial squeeze pressure 2600 psi at 1-1/2 BPM, final pressure 3600 psi locked up with 109 sacks below retainer. CIP at 0800 hours. Reversed out and POOH. Pressure tested 9-5/8" casing to 2500 psi for 30 minutes, OK. Bled 9-5/8" X 13-3/8" annulus from 140 psi to 0 psi immediately. Pumped in 8 barrels of barite pill to 2300 psi. Began replacing hydromatic over-riding clutch assembly at 2400 hours. Continued rig repair. RIH and drilled on cement retainer at 9512' at 2400 hours. Continued drilling retainer at 9520' and cement to 9699'. Pressure tested 9-5/8" casing & G-2 & 3 squeeze holes to 2500 psi. Tripped for bit #2. Drilled up retainer at 9699' and cement to top of 7" liner at 9785'. Sweep hole at 2400 hours. Pressure tested 9-5/8" casing and top of 7" liner at 2500 psi. Tripped for 6" bit. Drilled cement from 9799' - 9996', ROP 10-12 FPH. RIH and tagged retainer #3 at 10,000' DIL. Circulated clean and pressure tested 7" casing to 2500 psi, no good, bled back 500 psi in 15 minutes. Tripped for 7" & 9-5/8" scrapers in tandem, at 2400 hours. Run 9-5/8" and 7" scrapers in tandem to retainer @ 10,010'. CBU. POOH. RIH with 7" RTTS. Attempted to test G-5 perfs to 2500 psi. Bled to 1600 psi in 10 minutes. Attempted to break down same with 3700 psi without sUccess. Trip for bit. Drilled retainer @ 10,010' and cleaned out cement to 10,062'. RIH to retainer @ 10,192'. Drilled retainer @ 10,192' and firm cement to 10,290'. Tested casing to 2520 psi - bled to 1650 psi in 15 minutes. Trip for bit. Drilled cement and retainer @ 10,300' & cleaned out stringers to 10,370'. Pumped viscous sweep. Tested casing to 2480 psi - bled to 1440 psi in 15 minutes. POOH. Prep for BOPE test. Tested BOPE to UOC specifications. RIH and set RTTS @ 9815'. Established rate of 6 bpm @ 4400 psi below tool. Trip for 7" EZSV. Set same @ 9813'. Tested backside to 2500 psi. Pumped in @ 6 bpm w/ 4500 psi. Cement squeezed G-5, HB-1, HB-3 & HB-4 as follows: Unstung from retainer Pumped 20 bbls fresh water Mixed and pumped 300 sx (396 cu ft) of Cl "G" + 10% SSA-2 + 0.29% CFR-2 + 0.5% Halad - 334 + 0.1% LWL mixed @ 15.9 ppg. Displaced with 5 bbls fresh water Followed by 20.5 bbls of 3% KCL water Stung into retainer Total displacement of 156.5 bbls of KCL water. Initial: 4 bpm @ 3000 psi. Final: 3 bpm @ 4400 psi Formation 'held 3900 psi with pumps off. Unstung from retainer Pulled up to 9800' and reversed out 56 cuft cement. POOH. RIH with 6" cleanout assembly. Onload Dowell frac equipment while W.O.C. Cleanout cement and retainer to 10,227'. Continue to cleanout cement to 10,370' DPM, 10,360' DIL. Circulated high vis sweeps around. POOH. RIH w/ 7" scraper to 10,360' DIL. Tested casing to 2500 psi for 30 minutes. (Took 2 bbls to maintain 2500 psi.) Displaced hole to clean 3% KCL fluid. POOH. Rigged up Schlumberger and logged GR from 10,358' - 9250'DIL on two attempts. Rig up to perf HB-4. UNION O( :O. OF CALIFORNIA DRILLING RECORD PAGE NO ......... J~ LEASE, TB~S G-30 McArthur River Field WELL NO. FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11/02/87 11/03/87 , 11/04/87 , . 11/05/87 11/06/87 11/07/87 11/08/87 10,370' Perforated HB-4 10,330' - 10,340' DIL w/ 4 spf. RIH with RTTS and Sperry-Sun bundle carrier. Spotted Litesal pill on backside across G-2, 3, 4 & 5 and HB-1 & 3 perfs. Set R'I~S @ 10,294' DIL. Tested surface equipment to 10,000 psi and backside to 2500 psi. RIH with Sperry-Sun gauges on Schlumberger line to 10,300'DIL. Established rate of 15 bpm with 8900 psi with pre-pad in formation and displacing with KCL fluid. Initiated step rate test at 0.25 bpm. Ceased step rate test at 4 bpm with 6000 psi per John Smith of research. (He determined an insufficient rate to frac.) Pulled gauges. Rig up to acidize. W.O. acid. Received acid @ 0300 hrs. Tested lines. Attempted to acidizeHB-4 as follows: Open RTTS bypass. Pumped 25 bbls of 5% HC1 acid. Followed by 140 bbls of 3% KCL fluid. Closed bypass. Displace acid @ 1/4 bpm @ 3800 psi. Acid broke around into HB-3 perfs after 2 bbls of acid hit top of HB-4. Shut down and reverse out acid. POOH. RIH and reperforated HB-4 10,330' - 10,340' DIL and perforated additional HB-4 footage 10,320' - 10,330' DIL. RIH with RTTS and bundle carrier. Set packer at 10,185' (above HB-3 squeezed perfs); Tested lines. Began HB-4 data-frac pumping KCL fluid @ 15 bpm w/ 7000 psi. Continued data-frac as follows: Pumped an additional 200 bbls of 3% KCL fluid. Ran step rate test to 15 bpmbeginning @ 1/4 bpm. Shut down and monitored pressures. Pumped 400 bbls of cross-linked fluid with radioactive tracer. Followed by 90 bbls of cross-linked fluid without tracer. Followed by 82 bbls of KCL fluid. Shut down and monitored pressures. Pumped an additional 90 bbls of KCL fluid. Shut down and began Controlled flowback @ 1/2 bpm. (Flowback lasted 5 minutes.) Note: All pumping done @ 15 bpm except step rate test. POOH with wireline gauges. Ran temp and GR log. Logshowed majority of fluid staying in HB-4 but with some break through into HB-3. Filled and heated frac tanks. Began getting frac fluid. Continue gelling heated fluid. Begin pumping pad @ 0200 hrs. After pumping +50 bbls of cross-linked fluid the cross-linker injection pump failed. Shut down and waited on replacement parts until 1400 hrs. Repaired same and began testing injection system. Caustic tank for cross-linker was found to contain pieces of rubber from a worn suction hose. Dumped, cleaned and remixed new fluid. Testing cross-linker injection system. Continued working on Dowell activator pump system. Pumped 670 barrels of cross-linked fluid, began having problems with the gel not cross-linking. Had to shut down with 750 barrels pumped at 0400 hours to correct system. Released 7" RITS and displaced drill pipe with kill fluid. POOH. Filled all frac tanks with fresh water. Continued heating water at 2300 hours. Received two new activator pumps at 2400 hours. RIH with RTTS and bundle carrier. Set RTTS at 10,185' DPM and put 2500 psi on backside. Continued to heat water with platform steam. Could not heat above 77° F. Had supply boat deliver steam boiler (Veco). Continued heating water at 24OO hours. Continued heating water. Rigged up and tested frac lines to 10,000 psi. Pumped fracture stimulation as follows: 1125 barrels of gel at 15 BPM, 20 barrels of 2 ppg slurry at 15 bpm, 20 barrels of 4 ppg D~, ~_LING RECORD PAGE LEASE TBUS G-30 McArthur River Field WELL NO.. FIELD... DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11/09/87 11/10/87 11/11/87 11/12/87 11/13/87 11/14/87 11/15/87 10,129 10,360 9925 10,370 slurry at 15 BPM, 40 barrels of 6 ppg slurry at 15 BPM, 100 barrels of 7 ppg slurry at 15 BPM, 10 barrels of gel and 162 barrels of KCL fluids at 15 BPM. Shut-in for closure at 0600 hours. Bled off pressure from 300 psi to zero at 0815 hours, 1/4 barrel returns. Released RTTS and POOH. RIH with OE drill pipe. Reversed out from 10,109' - 10,370' and recovered +_2000 pounds of proppart. POOH. Rigged up Schlumberger at 2400 hours. Ran GR log from 10.370' tO 10,150' Log indicated proppant in both HB-3 & 4. RIH with open ended drill to 10,190'. Mixed and pumped 20 barrels of sand slurry with 28 sacks of 20-40 mesh sand. Tagged sand at 10,267'. Pulled to 10,000'. Mixed and pumped 50 barrels of sand slurry with 20 sacks of 20-40 mush sand and 15 sacks of 12-20 mesh sand. Tagged sand at 10,129'. Reversed clean and POOH. Wireline perforated from 10,068' - 10,078' (DIL) with 4 HPF. RIH with frac string at 2400 hours. Continued to RIH with frac string. Set RTTS at 10,000' DPM. Pressured backside to 2500 psi. Opened bypass and spotted sized salt pill across "G" zone perfs and closed bypass. Rigged up Dowell and Schlumberger to drill pipe and tested all equipment to 10,000 psi. Positioned wireline pressure gauge from 10,040' - 10,034'. Began injection at 15 BPM at 4780 psi with KCL fluid. Performed step rate injection test with KCL fluid. Pumped 174 barrels of cross-linked gel with tracer at 15 BPM. Drill pipe pressured up indicating it was plugged. Worked wireline out of hole. Rigged down Dowell and Schlumberger and opened bypass. Reversed clean with no sign of plugging material. Pulled RTTS loose and circulated clean. Re-set RTTS at 10,000' DPM. Retested backside and all equipment. Ran wireline pressure gauge and performed data frac. Pumped a total of 290 barrels of cross-linked gel and 84 barrels of KCL.' Flowed well back at 0.5 BPM until well died. POOH with wireline gauge. Ran GR log from 10,120' - 9785' at 2400 hours. With 7" RTTS at 10,000 DPM, sand frac'd HB-1 as follows: Pumped 670 barrels 8.4 PPG cross-linked gel, 30 barrels 3 PPG slurry, 30 barrels 4 PPG slurry, 30 barrels 5 PPG slurry, 40 barrels 6 PPG slurry, 70 barrels of 7 PPG slurry, and displaced with 10 barrels of gel and 160 barrels of 3% KCL. Initial rate of 15 BPM at 3000 psi, final of 15 BPM at 4400 psi. Shut-in at 0426 hours. ISIP was 3200 psi. Pressure after 1 hour was 800 psi. Bled off and POOH. RIH with OE drill pipe and reversed out sand from 9923' - 10,360' DIL. POOH and rigged up for GR-temp log at 2400 hours. Ran GR-NGT-temperature log from 10,367' -9750'. Ran and set 7" RBP at 10,000 DPM. Spotted 15 sacks of sand to 9925' DIL. Made up and ran tubing conveyed guns and positioned across G-2 thru G-5 sands. Located guns with GR. Displaced drill pipe through bypass with field gas to 2400' at 2400 hours. Displaced fluid in drill pipe to 2350' with field gas. Shot well with annulus fire tubing conveyed guns loaded with 4 HPF, 32 gram charges. Perforated intervals: G-2 9588' - 9610', G-3 9660' - 9681', G-4 9702' - 9766', G-5 9824' - 9857' and 9878' - 9892'. Reversed out and had no oil to surface. Pulled packer loose and POOH. RIH with 7" & 9-5/8" tandem scrapers to 9930'. Tripped for RBP overshot. Reversed out sand from 9925' - 9990'. Retrieved 7" RBP at 2400 hours. Ran a 6" bit, boot basket and 7" scraper to ETD at 10,370', no fill. POOH and laid down all drill pipe. Pulled wear bushing. Made gauge ring and junk basket run to 10,100'. Set Otis permanent packer on wireline at 9990'. Changed rams from 5" to dual 3-1/2" X 2-7/8" and tested. Unloaded and strapped 3-1/2" and 2-7/8" tubing at 2400 hours. Finished off-loading tubing. Made up 3-1/2" mule shoe, one joint of 3-1/2" tubing, X-nipple, one joint of 3-1/2" tubing, permanent packer seal assembly with chemical injection mandrel, and hooked up Camco dual encapsulated tubing. Ran 3-1/2" tubing to 3-1/2" blast joints. Blast joints had all bad threads. Sent blast joints to beach to be re-cut. Lost 14 hours. Continued running completion equipment at 2400 hours. UNION O(':': ;O. OF CALIFORNIA D .,.-LING RECORD PAGE '. LEASE TBUS G-30 McArthur River Field WELL NO. FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11/16/87 11/17/87 11/18/87 11/19/87 11/20/87 11/21/87 !1/22/87 11/23/87 11/24/87 10,370 Continued running, dual 3-1/2" X 2-7/8" production equipment with dual chemical injection equipment at 2400 hours. Continued running dual 3-1/2" X 2-7/8" completion with dual chemical injection line. Engaged permanent packer and sheared off latch. Landed tubing as follows: 3-1/2 mule shoe at 10,059', X-nipple at 10,030', Otis internal chemical injection mandrel at 9971', X-A sleeve at 9932', Baker 3-1/2" blast joints from 9902' - 9579', Otis dual packer at 9446', X-A sleeve at 9411', gas lift mandrels from 9374' - 2495', ball valve landing nipple at 337'. Short string mule shoe at 9469', X-nipple at 9466', Otis internal chemical injection mandrel at 9437', X-A sleeve at 9402', gas lift valves from 9307' - 2465', ball valve landing nipple at 304'. Pressure tested control lines and checked for packer communication. Set packer with 3100 psi. Left "PX" plug in X-A sleeve at 9932' until hole equalizes. Re-ran 3-1/2" dummy valve at 337' at 2400 hours. installed BPV's in tubing hangers. Nippled down BOPE and nippled up tree, tested tree to 5000 psi. Turned wellover to production at 0700 hours. Pulled BPV's and put well on gas lift. Load out rental equipment. At 1100 psi on 9-5/8" casing, 9-5/8" X 13-3/8" annulus had 1100 psi. Bled off both strings and attempted-to re-energize secondary packoff. Put 1380 psi on 9-5/8" casing and still had slight blow to 13-3/8" casing. Bled down both strings and readied rig to nipple up BOPE at 2400 hours. Set rotary table and built floor. Installed both BPV and nippled down tree. Nippled up BOPE andtested. Rigged up wireline~ With 3-1/2" plug in place at 9932', pulled dummy ball valve at 337'. Opened "XA" sleeve at 9411'. Circulated 280 barrels'of 64 pcf fluid down long string taking returns to production. Well stable. Worked dual hydraulic packer free with 40,000#. Well stable. Pulled 3-1/2" X 2-7/8" completion assembly at 2400 hours. Continued pulling 3,1/2" X 2'7/8" completion assembly at 2400 hours. Finished pulling dual completion assembly. RIH with 9-5/8" RBP and RTTS in tandem. Set RBP at 4515'. Set RTTS at 4382' and tested between tools to 2500 psi. Tested casing to surface to 2500 psi. Tripped for open ended drill pipe. Spotted 19 sacks of 20 - 40 mesh sand on top of RBP. Tagged sand at 4470'. Removed BOPE and found 12 - 3000 psi primary packoff not energized, upper snap ring missing and 12" X 9-5/8" secondary packoff deteriorated badly. The 9-5/8" casing stub had drill pipe wear. Energized primary packoff and installed top snap ring. Installed new DCB spool. Energized and tested secondary packoff to 2500 psi. Nippled up BOPE at 2400 hours. Tested BOPE. Reversed out sand and recovered RBP. Welded standoffs to blast joints to hold chemical line clamps. Waiting on wireline tools to recover clamps left in hole. RIH with slickline at 2400 hours. Continued to RIH with 4"-OD 4 prong internal wire grab and 8.37" OD gauge ring to top of 7" liner at 9785'. POOH, no recovery. RIH with 4 prong internal grab with 5.9" OD gauge ring to 9971'. POOH and recovered one band. Re-ran wireline tools to 9971'. POOH and recovered 6 bands. Re-ran wireline tools to 9971'. Worked tool and sheared-off. POOH with wireline. Fished and recovered wireline tools and 7 bands. Total of 14 bands recovered. Installed 3-1/2" X 5" VBR and tested. Off-loaded 3-1/2" drill pipe. Pick up fishing tools on drill pipe and RIH at 2400 hours. Continued to RIH with 6" OD finger junk basket on drill pipe'. Pumped 35 barrels of hi-vis pill and worked 'junk basket at 9965'. POH and had no recovery. RIH to retrieve Otis ratch-a-latch tool from perm packer at 9980' DPM. Rotated off ratch-a-latch. Sent retrieving tool into shop for machine work. Re-ran retrieving tool and engaged ratch-a-latch at 9980'. Rotated off and POH at 2400 hours. _ lNG RECORD LEASE TB~S G-30 McArthur River Field WELL NO. FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11/25/87 11/26/87 11/27/87 11/28/87 11/29/87 11/30/87 01/04/88 1/05/88 1/06/88 1/07/88 10,370' Continued toP O OH with ratch-a-latch assembly, recovered 13 bands on assembly. RIH with 2-7/8" tubing tail on drill pipe and tagged ETD at 10,370'. Tripped for Otis seal assembly. Tagged perm packer and tested seals at 1500 psi. POOH laying down drill pipe at 2400 hours. Continued.laying down drill pipe. Pulled wear bushing and installed test plug. Installed dual rams in BOPE and tested doors and hydril at 1500 psi. Removed test plug. Prep to run production equipment at 2400 hours. RIH with dual gas lift production assembly. Latched into Otis 7" perm packer and sheared off PBR with 20,0009. Spaced out and installed dual hangers. Completion included dual chemical injection lines. Long string mule shoe at 10,058', chemical injection mandrel at 9969', hydraulic packer at 9444' and ball valve at 336". Short string mule shoe at 9466', hydraulic packer at 9444' and ball valve at 303'. Rigged up wireline and pulled dummy ball valve from long string. Pressured up long string and set hydraulic packer. Retrieved PX plug from X nipple. Re-ran dummy ball valve. Tested packers by pumping down both strings with no returns. Installed BPV's in hangers and nippled down BOPE. Installed tree and tested to 5000 psi. Turned well over to production at 2400 hours, 11/27/87. Rigged down equipment and readied rig for move to leg 93. Moved equipment and began rigging up on leg #3. 'Moved equipment and began rigging up over G-36. .Continued to demobilize rigs. Rigged up wireline on G'30 long string. Pulled ball valve from 336'. Rigged up coiled tubing unit and tested equipment to 5000 psi. RIH and tagged fill at 10,362' DIL. Washed to ETD at 10,370' with 6% KCL with 1.5 PPB HEC at 1.75 BPM at 4000 psi. CBU at 2400 hours. Continue t° CBU. POOH and changed jetting tool. RIH to ETD @ 10,370' DIL with no signs of fill. POOH washing each GLM. Rigged down C.T.U. Wait on boat to bring out Gearhart electric line unit. Received Gearhart unit @ 0530 hrs. RU same. RIH and tagged ETD @ 10,364' DIL correlated with GR/CCL. Begin reperforatingHB 3 & 4 from 10,364' to 10,230' DIL with 2.50" O.D., 0° phasing, 16 gm, 4 spf through tubing guns. Continued to reperforate Hemlock benches 3 & 4 f/10,364' - 10,230'. Bench 1 f/10,058 - 10,088' with 2.50" O.D., 0° phasing, 16 gm, 4 spf through tubing guns. Returned well to production @ 1200 hrs. P~R and crews @ 1400 hrs, 1/7/88. 3-1/2", 9.29, N-80, Long String Tubing. From To Length Jts 10058.16 10057.66 .50 10057.66 10028.96 28.70 1 10028.96 10027.91 1.05 10027.91 9997.61 30.30 1 9997.61 9992.11 5.30 9992.11 9978.71 13.40 9978.71 9975.26 3.45 9975.26 9969.36 5.90 9969.36 9965.24 4.12 9965.24 9934.18 31.06 1 9934.18 9930.10 4.08 9930.10 9900.79 29.31 1 9900.79 9586.'92 313.87 9586.92 9577.28 9.64 9577.28 9454.16 123.12 4 Detail Decription 3-1/2" Mule Shoe 2-1/2" FL-45 Tbg. Otis 3-1/2" "X', Nipple 3-1/2" FL-45 Tbg. 3-1/2" N-80 Butt Ext. Otis Pbr W/ Ratch a Latch Assy Otis Pbr ExtW/X-Over Camco Chem Inj Mandrel 3-1/2 N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt Otis 3-1/2" "XA" Sliding Sleeve 3-1/2" N-80 Butt Baker 3-1/2" Blast Jts (16-20'long) Baker 3-1/2" Blast Jts (1-10'long) 3-1/2" N-80 Butt. UNION D~'~,O~''. ;O. OF CALIFORNIA ~LING RECORD PAGE T~S LEASE DATE E.T.D. ~0398N ( WELL NO, G-30. LS FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS From 9454.16 9444.51 9413.94 9409.94 9378.66 9372.16 9342.19 .9335.70 9306.06 9299.96 9178.43 9173.25 9081.69 9075.15 8709.76 '8703.20 8645.17 8640.08 8580.24 8576.12 8361.77 8356.69 8235.71 8229.17 8225.11 8045.11 8039.03 7859.08 7852.83 7640.01 7633.46 7181.05 7174.87 7169.54 7018.47 7014.37 6922.64 6916.14 6057.02 6050.52 5106.13 5100.87 4857.87 4851.32 3665.61 3659.11 3024.74 3020.64 2501.24 2494.74 2344.14 2338.89 2187.23 2182.12 1999.76 1994.46 1782.39 1777.09 1626.55 1621.30 1468.69 1463.54 1310.15 To 9444.51 9413.94 9409.94 9378.66 9372.16 9342.19 9335.70 9306.06 9299.96 9178.43 9173.25 9081.69 9075.15 8709.76 8703.20 8645.17 8640.08 8580.24 8576.12 8361.77 8356.69 8235.71 8229.17 8225.11 8045.11 8039.03 7859.08 7852.83 7640.01 7633.46 7181.05 7174.87 7169.54 7018.47 7014.37 6922.64 6916.14 6057.02 6050.52 5106.13 5100.87 4857.87 4851.32 3665.61 3659.11 3024.74 3020.64 2501.24 2494.74 2344.14 2338.89 2187.23 2182.12 1999.76 1994.46 1782.39 1777.09 1626.55 1621.30 1468.69 1463.54 1310.15 1305.02 Length. Jts Decription. 9.65 Otis 9-5/8" RDH Pkr. 30.57 1 1 Jt 3-1/2" N-80 Butt 4.00 Otis 3-1/2" "XA" Sleeve 31.28 1 3-1/2" N-80 Butt 6.50 Camco GLM 29.97 1 3-1/2" N-80 Butt 6.49 3-1/2" N-80 Butt Tbg Pup Jt 29.64 1 3-1/2" N-80 Butt 6.10 3-1/2" N-80 Butt Tbg Pup Jt 121.53 4 3-1/2" N-80 Butt 5.18 3-1/2" N-80 Butt Tbg Pup Jt 91.56 3 3-1/2" N-80 Butt 6.54 Camco GLM 365.39 12 3-1/2" N-80 Butt 6.56 Camco GLM 58.03 2 3-1/2" N-80 Butt 5.09 3-1/2" N-80 Butt Tbg Pup Jt 59.84 2 3-1/2" N-80 Butt 4.12 3-1/2" N-80 Butt Tbg Pup Jt 214.35 7 3-1/2" N-80 Butt 5.08 3'1/2" N-80 Butt Tbg Pup Jt. 120.98 4 3-1/2" N-80 Butt 6.54 Camco GLM 4.06 3-1/2" N-80 Butt Tbg Pup Jt 180.00 6 3-1/2', N-80 Butt 6.08 3-1/2" N-80 Butt Tbg Pup Jt 179.95 7 3-1/2" N-80 Butt 6.25 3-1/2" N-80 Butt Tbg Pup Jt. 212.82 7 3-1/2" N-80 Butt 6.55 Camco GLM 452.41 15 3-1/2" N-80 Butt 6.18 3-1/2" N-80 Butt Tbg Pup Jt 5.33 3-1/2" N-80 Butt Tbg Pup Jt 151.07 5 3-1/2" N-80 Butt 4.10 3-1/2" N-80 Butt Tbg Pup Jt. 91.73 3 3-1/2" N-80 Butt 6.50 Camco GLM 859.12 28 3-1/2" N-80 Butt 6.50 Camco GLM 944.39 31 3-1/2" N-80 Butt 5.26 3-1/2" N-80 Butt Tbg Pup Jt 243.00 8 3-1/2" N-80 Butt 6.55 Camco GLM 1185.71 39 3-1/2" N-80 Butt 6,50 Camco GLM 634.37 21 3-1/2" N-80 Butt 4.10 3-1/2" N-80 Butt Tbg Pup Jt 519.40 17 3-1/2" N-80 Butt 6.50 Camco GLM 150.60 5 3-1/2" N-80 Butt 5.25 3-1/2" N-80 Butt Tbg Pup Jt 151.66 5 3-1/2" N-80 Butt 5.11 3-1/2" N-80 Butt Tbg Pup Jt 182.36 6' 3-1/2" N-80 Butt 5.30 3-1/2" N-80 Butt Tbg Pup Jt 212.07 7 3-1/2" N-80 Butt 5.30 3-1/2" N-80 Butt Tbg Pup Jt 150.54 5 3-1/2" N-80 Butt 5.25 3-1/2" N-80 Butt Tbg Pup Jt 152.61 5 3-1/2" N-80 Butt 5.15 3-1/2" N-80 Butt Tbg Pup Jt 153.39 5 3-1/2" N-80 Butt 5.13 3-1/2" N-80 Butt Tbg Pup Jt LEASE TBUS O,1~" ;O. OF CALIFORNIA UNION D ._LING RECORD PAGE G-30 LS McArthur River Field WELL NO. FIELD. DATE 90398N ( E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS From To 1305.02 1217.37 1212.tl 1093.64 1088.32 813.44 808.26 563.78 558.48 466.44 461.25 338.94 336.19 59.82 55.60 51.40 47.15 43.00 4.2.00 1217.37 1212.11 1093.64 1088.32 813.44 808.26 563.78 558.48 466.44 461.25 338.94 336.19 59.82 55.60 51.40 47.15 43.00 42.00 0 Length Jt's D. ecription 87.65 3 3-1/2" N-80 Butt 5.26 3-1/2" N-80 Butt Tbg Pup Jt 118.'47 4 3-1/2" N-80 Butt 5.32 3-1/2" N-80 Butt Tbg Pup Jt 274.88 9 3-1/2" N-80 Butt 5.18 3-1/2" N-80 Butt Tbg Pup Jt 244.48 8 3-1/2" N-80 Butt 5.30 3-1/2" N-80 Butt Tbg Pup Jt 92.04 3 3-1/2" N-80 Butt 5.19 3-1/2" N-80 Butt Tbg Pup Jt 122.31 4 3-1/2" N-80 Butt 2.75 Otis 3-1/2" Ball Valve Nipple 276.37 9 3-1/2" N-80 Butt 4.22 3-1/2" N-80 Butt Tbg Pup Jt 4.20 3-1/2" N-80 Butt Tbg Pup Jt 4.25 3-1/2" N-80 Butt Tbg Pup Jt 4.15 3-1/2" N-80 Butt Tbg Pup Jt 1.00 Camron Dual Tbg Hanger 42.00 Landed Below Zero 2-7/8", 6.4#, N-80, Buttress 9466.34 9465.54 .80 9465.54 9464.14 1.40 9464.14 9454.16 9.98 9454.16 9444.51 9.65 9444.51 9435.31 9.20 9435.31 9403.69 31.62 9403.69 9399.64 4.05 9399.64 9305.06 94.58 9305.06 9298.51 6.55 9298.51 9083.75 214.76 9083.75 9077.87 5.88 9077.87 8707.55 370.32 8707.55 8702.27 5.28 8702.27 8696.15 6.12 8696.15 8363.21 332.94 8363.21 8356.60 6.61 8356.60 8204.63 151.97 8204.63 8198.74 5.89 8198.74 7643.08 555.66 7643.08 7637.39 5.69 7637.39 7177.03 460.36 7177.03 7170.53 6.50 7170.53 6919.86 250.67 6919.86 6915.94 3.92 6915.94 6461.60 454.34 6461.60 6456.40 5.20 6456.40 6217.'25 239.15 6217.25 6211.93 5.32 6211.93 6028.44 183.49 6028.44 6021.84 6.60 6021.84 5626.33 395.51 5626.33 5621.33 5.00 5621.33 ~5323.23 298.10 5323.23 5318.18 5.05 5318.18 4828.38 489.80 4828.38 4821.78 6.60 4821.78 4702.55 119.23 4702.55 4696.45 6.10 4696.45 3639.57 1056.88 Short String ~ubiqg Detail 1 3 7 12. 11 5 18 15 8 15 8 6 13 10 16 4 35 Mule Shoe Otis 'XN' nipple 2-7/8" N-80 Butt. tbg. pup jt. Otis 9-5/8" R.D.H. Packer Camco Chemical Injection Mandrel 2-7/8" N-80 Butt. Otis 2-7/8" "XA" Slidding Sleeve 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. ,1 I, ,1 I1 ,! 11 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" n-80 Butt. 2-7/8" Butt. tgb. pup jt. 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-8- Butt. pup jt. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg pup jt. 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. UNION '~O. OF CALIFORNIA ~_LING RECORD TBUS G-30 LS LEASE WELL NO. FIELD PAGE McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 2-7/8", 6.4~, N-80, Buttress Short Strin~ Tubing Detail From To Length Jts. Decription 3639.57 3632.92 6.65 3632.92 .3425.67 207.25 3425.67 3420.59 5.08 3420.59 2689.81 730.78 2689.81 2684.68 5.13 2684.68 2471.13 213.55 2471.13 2464.53 6.60 2464.13 310.98 2153.55 310.98 305.69 5.29 305.69 303.39 2.30 303.39 56.70 246.69 56.70 46.52 10.18 46.52 45.40 1.12 45.40 43.00 2.40 43.00 42.00 1.00 42.00 0 42.00 7 24 7 69 Camco Glm. 2-7/8" N-80 Butt. · 2-7/8 N-80 Butt. tbg pup it. 2-7/8 N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. Otis Ball Valve Nipple. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" X 3-1/2" N-80 Butt. X-over 3-1/2" N-80 Butt. tbg. pup jt. Camco duel tbg hanger 3-1/2" Butt. X 3-1/2" 8 R Landed below zero Note: There is 3/8" Incapsilated tbg running f/ tbg hanger to chemical ih'j "mandrel. The 3/8" tbg is clamped to 2-7/8" short string w/Camco Clamps. There is 1/4" stainless tbg. f/ tbg hanger to Otis Ball Valve. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging i-q Perforate ~ Pull tubing Alter Casing [] Other [] 99519-0247 2. Name of Operator Union Oil Company of California 3. Address P.O. Box 190247, Anchorage,'Alaska 4. Location of wellatsurface 1876' N & 1378' W f/SE Cr.,' See 29, T9N, R13W, SM At topof productive interval · 2511' S & 2173' E f/ Surface LOcation At effective depth 2848' S & 2286' E f/ Surface Location At total depth 3377' S & 2414' E f/ Surface Location 5. Datum elevation (DF or KB) 99' RT above MSL 6. Unit or Property name Trading Bay Unit 7. Well number G-30 11,451 feet Plugs (measured) 10,329 feet 8. Approvalnumber 7-308 9. APInumber 50--133-20187 10. Pool McArthur River Field 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 10,370 feet Junk (measured) true vertical 9,397 feet Casing Length Size Structural 365 ' 26" Oonductor 520' 17.3/4" Surface 4,779' 13-3/8" Intermediate 9,866' 9-5/8" Production Liner 1,659' Perforation depth: measured Feet Cemented Measured depth ~ueVerticaldepth Driven 365' 365' 750 sx 520' 520' 2,200 sx 4,779' 4,486' 1,800 sx 9,866' 8,950' 7" 1,000 sx 9785''i1~'4~4' ' , See attached true vertical Tubing (size, grade and measured depth) LS 3-1/2", 9.2#, N-80 @ 10,058' SS 2-7/8", 6.4#, N-80 @ 9,454' APl? 25 Alaska Oil & Gas Cons. Comrnissk Anchorage Treatment description including volumes used and final pressure 13. OiI-Bbl Gas-Mcf Water-Bbl SS 85 - 13 Prior to well operation LS 234 - 208 SS 135 43 15 Subsequent to operation LS 67 57 268 14. Attachments Daily Report of Well oPerations [] Representative Daily Average Production or Injection Data Casing Pressure 790 psi 790 psi 1215 psi 1215 psi ~bing Pressure 110 psi 100 psi 110 psi 80 psi Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true an~ colrecttto the best of my knowledge Signed //~g~, ~. /~:2'~.,~ -~4~'Title Environmental Engineer Form 10-404 Rev. 12-1-85 Roy D. ~ts \ Date 4/22/88 Submit in Duplicate Packers and SSSV (type and measured depth) Otis 9-5/8" R.D.H. Pkr. @9,444' Otis 7" perm packer @ 9~98.0' Otis 3-1/2" Ball ValVe Nipple 0 336' & 303' 12. Stimulation or cement squeeze summary See attached Intervals treated (measured) TBUS G-30 PERFORATION RECORD G-2 G-3 G-4 G-5 G-5 9,588' - 9,610' 9,660' - 9,681' 9,702' - 9,766' 9,824' - 9,857' 9,878' - 9,892' "G" ZONE 8,701' - 8,720' 8,765' - 8,784' 8,802' - 8,860' 8,912' - 8,942' 8,961' - 8,973' HB-1 HB-3 & 4 10,058' - 10,088' 10,230'- 10,364' HEMLOCK BENCH 9,122' - 9,149' 9,274' - 9.392' CLL/sp 0505N RECEIVED Aiqcitora~ TBUS G-30 CEMENT SUMMARY INTERVAL SQUEEZED "G" Zone VOLUME CEMENT cu. ft. FINAL PRESSURE psi G 2-3 G 4-5 9,588' - 9,681' 9,702' - 9,892' 3700 3600 HEMLOCK HB 1 HB 3 HB 4-6 10,058' - 10,088' 10,230' - 10,280' 10,300' - 10,585' 8O 123 71 3600 3700 3600 G5 & HB 1,3,4 9,824' - 10,390' 396 4400 CLL/sp 0505N TBUS G-30 STIMULATION SUMMARY Data Fractured HB-4 (10,320' - 10,340') as follows: 372 bbls of 3% KCL Fluid 400 bbls cross-linked gel w/radioactive tracer 90 bbls cross-linked gel w/o radioactive tracer Sand Fractured HB-4 as follows: 1125 bbls cross-linked gel 20 bbls 2 ppg slurry 20 bbls 4 ppg slurry 40 bbls 6 ppg slurry 100 bbls 7 ppg slurry displaced w/ 10 bbls of gel and 162 bbls 3% KCL @ 300 psi. Data Fractured HB-1 (10,068'-10,078') as follows: 84 bbls of 3% KCL Fluid 290 bbls cross-linked gel Sand Fractured HB-1 as follows: 670 bbls 30 bbls 30 bbls 30 bbls 40 bbls 70 bbls 8.4 ppg cross-linked gel 3 ppg slurry 4 ppg slurry 5 ppg slurry 6 ppg slurry 7 ppg slurry Displaced w/10 bbls of gel and 160 bbls 3% KCL @ 4400 psi CLL/sp 0505N A, tasl~a Oil & Bas Cons, Anchor~9'~ GRAYLING PLATFORM TRADING BAY UNIT G-30 ~ 7-3/4" c._ O 520'MD SS: 2-7/8" 6.4~ N-BO SEAL LOCK e 9454'UD /1 13-3/8" C. · 4779'MD /__J OTIS 9-5/8" DUAL PKR. ~ 9444'MD OTIS 7" W.D. PERM PKR, · ' 9980'MD 7" LINER F/ 9785'-11444'MD Z "O" ZONE 9588'-9610' (22') 9660'-9681' (21') 9702'-9766' (64') 9824'-9857' (33') 9818'-9892' (14') LS: 3-1/2" 9.2# N-80 SEAL LOCK e 10058'MD HEMLOCK BENCHES oosa'-~ ooss' (309 0230'- 10364' (134') ETD 10370' CMT PLUG I. JNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. LEASE DATE 1987 GRAYLING 10-02-87 10-03-87 10-04-87 10-05-87 10-06-87 10-07-87 10-08-87 10-09-87 10-10-87 10-11-87 10-12-87 10-13-87 TBUS E.T.D. HISTC 10,020 9,353 5,867' 10,020' 10,030 10,400 G-30 McArthur River Field WELL NO, FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Worked tubing stop out of hole (recovered several pieces of wire with ct)..Fished and recovered prong. Latched onto SSSV and could not jar up or down. Ran prong and tubing stop back in SSSV. Released rig at 1200 hours, 102/87. Continued moving rig ~54 from leg ~3 to leg ~2 at 2400 hours. Continued rigging up on leg ~2 at 2400 hours. Moved rig over G-30. Rigging up slickline and ran a gauge cutter to ball valve at 300'. Retrieved ball valve from both long and short strings. RIH to shift sleeve in long string at 9395' at 2400 hours. Unable to open long string sleeve at 9395' or 9453'. Tripped for jet cutter. Cut long string at 9462'. Displaced tubing and rathole with 6% KCL and spotted a sized salt pill across perfs. Perfed long string at 9342'. Circulated well dead with 6% KCL. Installed BPV's 5nd removed tree. Nippled up riser at 2400 hours. Continued rigging up stack. Tested BOPE. Attempted to pull dual packer free without success. Cut long string with jet cutter at 9353'. Pulled and recovered tubing and production equipment from 9353'. Laid down production equipment at 2400 hours. Installed and tested 2-7/8" rams. Verified short string fish at 1270' with slickline run. Performed manual backoff on short string and recovered tubing and production equipment. Top of short string at 5867'. Installed and tested 5" rams. RIH with 3-1/2" grapple and overshot on 5" drill pipe. Engaged fish at 5867'. RIH with jet cutter at 2400 hours. Cut off 2-7/8" short string at 9283'. POOH and laid down production equipment and tubing. Found and recovered several thousand feet of slickline in t~ing fish. RIH with overshot and tagged fish at 9285'. Could not mill over fish. Tripped for mill shoe and 12' extension at 2400 hours. Worked over short string fish from 9285' to 9297'. POOH and recovered a ball of wire. RIH with overshot and grapple. Engaged top of fish at 9285' and performed manual back. POOH and laid down tubing and pups. RIH and engaged fish at 9328'. Ran jet cutter, stopped at 9360'. Ran string shot to 9420' and performed controlled back-off at to, of dual packer. Rigged down wireline at 2400 hours. POOH and laid down fish. Changed to pipe rams to 3-1/2" X 5" variable and tested. RIH with overshot and engaged top of long string at 9365'. Jarred dual packer free and circulated bottoms up. POOH and laid down production equipment. RIH with overshot and engaged long string at 9476'. Jarred tubing and seals free from permanent packer. Circulated clean at 2400 hours. Laid down remainder of long string and seal assembly. RIH with 6" bit and scraper. Washed from 9972' - 10,028' (top of packer). CBU. Tripped for 6" mill shoe. Milled over packer from 10,028' - 30' and packer came loose. CBU and POOH at 2400 hours. Laid down packer seal bore and bottom slips. Ring nut left in hole. RIH with 6" burn over shoe and tagged junk at 10,058'. Pushed junk to 10,322'. Milled junk to 10,369', could not go any deeper. Circulated clear and POOH. Junk baskets were full of miscellaneous junk and wire. RIH with 6" flat bottom mill and cleaned out from~%l~_~3~ 10,369'. Milled junk to 10,376' at 2400 hours. tJNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. '~. LEASE WELL NO. - -~ FIELD i-;cA:Lhu: Kiw~ Field DATE 10-14-87 10-15-87 10-16-87 10-17-87 10-18-87 10-19-87 10-20-87 10-21-87 10-22-87 10-23-87 E.T.D. 10.383' 10,384' 10,393 10,290 10,182 9,512 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Circulated and pumped hi-vis sweeps at 10,376'. Tripped for 6" burn over shoe. Worked junk from 10,375' - 10,376' and milled on junk at 10,376' without success. Pulled to 9500' and repaired brake water cooling pump. POOH. Boot baskets full of misc junk. RIH with 6" flat bottom mill. Milled and worked junk from 10,376' - 10,383'. Pumped sweeps at 2400 hours. Continued milling on junk at 10,383'. Tripped for new mill. Milled on junk with flat bottom mill at 10,383' without success. POOH and recovered small amounts of junk in the boot basket. Changed out brake blocks. Tested BOPE. RIH with 6" burn-over shoe at 2400 hours. Milled on junk with 6" burn-over shoe at 10,383' without success. RIH with 3" X 5-3/4" tapered mill. Milled on junk and made 1-2 inches. Tripped for burn-over shoe. Milled on junk at 10,383' at 2400 hours. Continued milling on junk at 10,383'. Tripped for new burn-over shoe. Milled on junk at 10,383' without success. Tripped for new burn-over shoe. Milled on junk at 2400 hours. Continued milling on junk at 10,383'. Tripped for new mill shoe with diamond cutters. Pumped hi-vis sweeps. Milled on junk to 10,384' at 2400 hours. POOH with mill shoe, indicated being over junk 14". RIH with overshot and 4-5/8" grapple. Worked over fish to 10,384'. POOH with no recovery. RIH with 6" impression block. Tagged fish at 10,383'. POOH. Impression block indicated two sinker bars side-by-side. RIH with 4-3/4" X 3-1/2" ID box tap. Worked over fish at 10,384'. Kept pulling off with 8-10,000~ over-pull. Tripped for 3-5/8" X 2-5/8" box tap at 2400 hours. Continued RIH with 5,7/8" OD box tap with 2-5/8" ID. Worked over junk at 10,383'. Pulled off junk with 35,0009 over-pull. POOH and recovered 2 pieces of wireline sinker bar (5.08' and 1.35'). RIH with burn over shoe and mill on junk from 10,384' - 10,386'. Pushed junk to 10,393'. Trip for combination overshot. Attempted to catch fish at 10,393' without success. Laid down fishing tools at 2400 hours. Performed weekly BOPE test. RIH with 6" bit and 7" scraper to 10,393'. Pumped 30 barrel HI-VIS PILL. POOH. Ran wireline gauge ring and junk basket to 10,350'. Ran a GR-CCL strip from 10,350' - 9249'. RIH and set a cement retainer at 10,290' DIL. Tripped for drill pipe and stinger. Stabbed into retainer and obtained an injection rate of 1/2 BPM at 2850 psi at 2400 hours. With 7" retainer at 10,290' DIL, pump 10 bbl fresh water and 125 sacks (154 ft 3) of Class "G" cement with 10% 100 mesh sand and additives. Initial squeeze pressure of 2300 psi at 3/4 BPM. Final squeeze was 3600 psi at 0 BPM. Total of 58 sacks (71 ft3) below retainer. CIP at 0215 hours. Reversed out and POOH. Ran an 8-1/2" bit and 9-5/8" scraper to TOLat 9785'. Circulated clean and POOH. Ran and set a cement retainer at 10,182'. DIL. Tested surface cementing equipment to 4000 psi. Cemented Bench 3 with 15 barrels of fresh water ahead followed by 100 sacks of Class "G" cement with 10% 100 mesh and additives. Initial squeeze pressure of 3000 psi at 3/4 BPM. Final squeeze pressure of 3700 psi at 0 BPM. Reversed out and POOH at 2400 hours. Continued to POOH with retainer stinger. Set retainer 93 on drill pipe at 10,000' DIL. Rigged up Howco and tested lines to 4000 psi. Cemented through retainer with 15 barrels of fresh water ahead followed by 150 sacks of Class "G" neat cement with additives followed by 5 barrels of fresh water. Initial squeeze pressure 2550 psi at 1 BPM, final pressure of 3600 psi locked up with 65 sacks below retainer. CIP at 0930 hours. Reversed out and POOH. Set retainer ~4 on wireline at 9691' DIL. RIH and stung into retainer. Tested surface lines to 4000 psi. Cemented through retainer with 15 barrels of fresh water ahead UnlIION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. LEASE TBUS G-30 McArthur River Field WELL NO FIELD DATE E.T.D. 10-24-87 10-25-87 10-26-87 10-27-87 10-28-87 10-29-87 10-30-87 10/31/87 11/01/87 9785' 10,000' 10,192' 10,370 9813' 10,227' 10,370' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS followed by 150 sacks of Class "G" cement with 10% 100 mesh sand and additives followed by 5 barrels of fresh water. Initial squeeze pressure 2300 psi at 1 BPM, final pressure 3700 psi locked up with 73 sacks below retainer. CIP at 2200 hours. Reversed out and POOH at 2400 hours. Continued to POOH with cement stinger. Set retainer #5 on drill pipe at 9512' DIL. Stung into retainer. Tested surface line to 4000 psi. Cemented through retainer. Tested surface line to 4000 psi. Cemented through retainer with 125 sacks of Class "G" cement with 10% 100 mesh sand and additives. Initial squeeze pressure 2600 psi at 1-1/2 BPM, final pressure 3600 psi locked up with 109 sacks below retainer. CIP at 0800 hours. Reversed out and POOH. Pressure tested 9-5/8" casing to 2500 psi for 30 minutes, OK. Bled 9-5/8" X 13-3/8" annulus from 140 psi to 0 psi immediately. Pumped in 8 barrels of barite pill to 2300 psi. Began replacing hydromatic over-riding clutch assembly at 2400 hours. Continued rig repair. RIH and drilled on cement retainer at 9512' at 2400 hours. Continued drilling retainer at 9520' and cement to 9699'. Pressure tested 9-5/8". casing & G-2 & 3 squeeze holes to 2500 psi. Tripped for bit ~2. Drilled up retainer at 9699' and cement to top of 7" liner at 9785'. Sweep hole at 2400 hours. Pressure tested 9-5/8" casing and top of 7" liner at 2500 psi. Tripped for 6" bit. Drilled cement from 9799' - 9996', ROP 10-12 FPH. RIH and tagged retainer 93 at 10,000' DIL. Circulated clean and pressure tested 7" casing to 2500 psi, no good, bled back 500 psi in 15 minutes. Tripped for 7" & 9-5/8" scrapers in tandem, at 2400 hours. Run 9-5/8" and 7" scrapers in tandem to retainer @ 10,010'. CBU. POOH. RIH with 7" RTTS. Attempted to test G-5 perfs to 2500 psi. Bled to 1600 psi in 10 minutes. Attempted to break down same with 3700 psi without success. Trip for bit. Drilled retainer @ 10,010' and cleaned out cement to 10,062'. RIH to retainer @ 10,192'. Drilled retainer @ 10,192' and firm cement to 10,290'. Tested casing to 2520 psi - bled to 1650 psi in 15 minutes. Trip for bit. Drilled cement and retainer @ 10,300' & cleaned out stringers to 10,370' Pumped viscous sweep. Tested casing to 2480 psi - bled to 1440 ~si in 15 minutes. POOH. Prep for BOPE test. Tested BOPE to UOC specifications. RIH and set RTTS @ 9815'. Established rate of 6 bpm @ 4400 psi below tool. Trip for 7" EZSV. Set same @ 9813'. Tested backside to 2500 psi. Pumped in @ 6 bpm w/ 4500 psi. Cement squeezed G-5, HB-1, HB-3 & HB-4 as follows: Unstung from retainer Pumped 20 bbls fresh water Mixed and pumped 300 sx (396 cu ft) of Cl "G" + 10%~0~2~· '~'~ CFR-2 + 0.5% Halad- 334 + 0.1% LWL mixed @ 15.9 ppg. APR 2'i.~ .... ~ ~ Displaced with 5 bbls fresh water '' ~ Followed by 20 5 bbls of 3% KCL water .~da~k~ n:. ~ Stung into retainer ~ ..... Total displacement of 156.5 bbls of KCL water. ' .......... ~" Initial: 4 bpm @ 3000 psi. Final: 3 bpm @ 4400 psi Formation held 3900 psi with pumps off. Unstung from retainer Pulled up to 9800' and reversed out 56 cu ft cement. POOH. RIH with 6" cleanout assembly. Onload Dowell frac equipment while W.O.C. Cleanout cement and retainer to 10,227'. Continue to cleanout cement to 10,370' DPM, 10,360' DIS. Circulated high vis sweeps around. POOH. RIH w/ 7" scraper to 10,360' DIL. Tested casing to 2500 psi for 30 minutes. (Took 2 bbls to maintain 2500 psi.) Displaced hole to clean 3% KCL fluid. POOH. Rigged up Schlumberger and logged GR from 10,358' - 9250'DIL on two attempts. LINION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. TBUS G-30 McArthur River Field LEASE WELL NO FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11/02/87 11/03/87 11/04/87 11/05/87 11/06/87 11/07/87 11/08/87 10,370' Perforated HB-4 10,330' - 10,340' DIL w/ 4 spf. RIH with RTTS and Sperry-Sun bundle carrier. Spotted Litesal pill on backside across G-2, 3, 4 & 5 and HB-1 & 3 perfs. Set RTTS @ 10,294' DIL. Tested surface equipment to 10,000 psi and backside to 2500 psi. RIH with Sperry-Sun gauges on Schlumberger line to 10,300'DIL. Established rate of 15 bpm with 8900 psi with pre-pad in formation and displacing with KCL fluid. Initiated step rate test at 0.25 bpm. Ceased step rate test at 4 bpm with 6000 psi per John Smith of research. (He determined an insufficient rate to frac.) Pulled gauges. Rig up to acidize. W.O. acid. Received acid @ 0300 hrs. Tested lines. Attempted to acidize HB-4 as follows: Open RTTS bypass. Pumped 25 bbls of 5% HC1 acid. Followed by 140 bbls of 3% KCL fluid. Closed bypass. Displace acid @ 1/4 bpm @ 3800 psi. Acid broke around into HB-3 perfs after 2 bbls of acid hit top of HB-4. Shut down and reverse out acid. POOH. RIH and reperforated HB-4 10,330' - 10,340' DIL and perforated additional HB-4 footage 10,320' - 10,330' DIL. RIH with RTTS and bundle carrier. Set packer at 10,185' (above HB-3 squeezed perfs); Tested lines. Began HB-4 data-frac pumping KCL fluid @ 15 bpm w/ 7000 psi. Continued data-frac as follows: Pumped an additional 200 bbls of 3% KCL fluid. Ran step rate test to 15 bpm beginning @ 1/4 bpm. Shut down and monitored pressures. Pumped 400 bbls of cross-linked fluid with radioactive tracer. Followed by 90 bbls of cross-linked fluid without tracer. Followed by 82 bbls of KCL fluid. Shut down and monitored pressures. Pumped an additional 90 bbls of KCL fluid. Shut down and began controlled flowback @ 1/2 bpm. (Flowback lasted 5 minutes.) Note: All pumping done @ 15 bpm except step rate test. POOH with wireline gauges. Ran temp and GR log. Log showed majority of fluid staying in HB-4 but with some break through into HB-3. Filled and heated frac tanks. Began getting frac fluid. Continue gelling heated fluid. Begin pumping pad @ 0200 hrs. After pumping +50 bbls of cross-linked fluid the cross-linker injection pump failed. --Shut down and waited on replacement parts until 1400 hrs. Repaired same and began testing injection system. Caustic tank for cross-linker was found to contain pieces of rubber from a worn suction hose. Dumped, cleaned and remixed new fluid. Testing cross-linker injection system. Continued working on Dowell activator pump system. Pumped 670 barrels of cross-linked fluid, began having problems with the gel not cross-linking. Had to shut down with 750 barrels pumped at 0400 hours to correct system. Released 7" RTTS and displaced drill pipe with kill fluid. POOH. Filled all frac tanks with fresh water. Continued heating water at 2300 hours. Received two new activator pumps at 2400 hours. RIH with RTTS and bundle carrier. Set RTTS at 10,185' DPM and put 2500 psi on backside. Continued to heat water with platform steam. Could not heat above 77° F. Had supply boat deliver steam boiler (Veco). Continued heating water at 2400 hours. Continued heating water. Rigged up and tested frac lines to 10,000 psi. Pumped fracture stimulation as follows: 1125 barrels of gel at 15 BPM, 20 barrels of 2 ppg slurry at 15 bpm, 20 barrels of 4 ppg LEASE TBUS ,/.~ ,.~',~ bNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. G-30 McArthur River Field WELL NO FIELD .. E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DATE 11/09/87 11/10/87 11/11/87 11/12/87 11/13/87 11/14/87 11/15/87 10,129' 10,360 9925 10,370 slurry at 15 BPM, 40 barrels of 6 ppg slurry at 15 BPM, 100 barrels of 7 ppg slurry at 15 BPM, 10 barrels of gel and 162 barrels of KCL fluids at 15 BPM. Shut-in for closure at 0600 hours. Bled off pressure from 300 psi to zero at 0815 hours, 1/4 barrel returns. Released RTTS and POOH. RIH with OE drill pipe. Reversed out from 10,109' - 10,370' and recovered +2000 pounds of proppart. POOH. Rigged up Schlumberger at 2400 hours. Ran GR log from 10.370' tO 10,150'. Log indicated proppant in both HB-3 & 4. RIH with open ended drill to 10,190'. Mixed and pumped 20 barrels of' sand slurry with 28 sacks of 20-40 mesh sand. Tagged sand at 10,267'. Pulled to 10,000'. Mixed and pumped 50 barrels of sand slurry with 20 sacks of 20-40 mush sand and 15 sacks of 12-20 mesh sand. Tagged sand at 10,129'. Reversed clean and POOH. Wireline perforated from 10,068' - 10,078' (DIL) with 4 HPF. RIH with frac string at 2400 hours. Continued to RIH with frac string. Set RTTS at 10,000' DPM. Pressured backside to 2500 psi. Opened bypass and spotted sized salt pill across "G" zone perfs and closed bypass. Rigged up Dowell and Schlumberger to drill pipe and tested all equipment to 10,000 psi. Positioned wireline pressure gauge from 10,040' - 10,034'. Began injection at 15 BPM at 4780 psi with KCL fluid. Performed step rate injection test with KCL fluid. Pumped 174 barrels of cross-linked gel with tracer at 15 BPM. Drill pipe pressured up indicating it was plugged. Worked wireline out of hole. Rigged down Dowell and Schlumberger and opened bypass. Reversed clean with no sign of plugging material. Pulled RTTS loose and circulated clean. Re-set RTTS at 10,000' DPM. Retested backside and all equipment. Ran wireline pressure gauge and performed data frac. Pumped a total of 290 barrels of cross-linked gel and 84 barrels of KCL. Flowed well back at 0.5 BPM until well died. POOH with wireline gauge. Ran GR log from 10,120' - 9785' at 2400 hours. With 7" RTTS at 10,000 DPM, sand frac'd HB-1 as follows: Pumped 670 barrels 8.4 PPG cross-linked gel, 30 barrels 3 PPG slurry, 30 barrels 4 PPG slurry, 30 barrels 5 PPG slurry, 40 barrels 6 PPG slurry, 70 barrels of 7 PPG slurry, and displaced with 10 barrels of gel and 160 barrels of 3% KCL. Initial rate of 15 BPM at 3000 psi, final of 15 BPM at 4400 psi. Shut-in at 0426 hours. ISIP was 3200 psi. Pressure after 1 hour was 800 psi. Bled off and POOH. RIH with OE drill pipe and reversed out sand from 9923' - 10,360' DIL. POOH and rigged up for GR-temp log at 2400 hours. Ran GR-NGT-temperature log from 10,367' -9750'. Ran and set 7" RBP at 10,000 DPM. Spotted 15 sacks of sand to 9925' DIL. Made up and ran tubing conveyed guns and positioned across G-2 thru G-5 sands. Located guns with GR. Displaced drill pipe through bypass with field gas to 2400' at 2400 hours. Displaced fluid in drill pipe to 2350' with field gas. Shot well with annulus fire tubing conveyed guns loaded with 4 HPF, 32 gram charges. Perforated intervals: G-2 9588' - 9610', G-3 9660' - 9681', G-4 9702' - 9766', G-5 9824' - 9857' and 9878' - 9892'. Reversed out and had no oil to surface. Pulled packer loose and POOH. RIH with 7" & 9-5/8" tandem scrapers to 9930'. Tripped for RBP overshot Reversed out sand from 9925' - 9990'. Retrieved 7" RBP at 2400 hours[ Ran a 6" bit, boot basket and 7" scraper to ETD at 10,370', no fill. POOH and laid down all drill pipe. Pulled wear bushing. Made gauge ring and junk basket run to 10,100'. Set Otis permanent packer on wireline at 9990'. Changed rams from 5" to dual 3-1/2" X 2-7/8" and tested. Unloaded and strapped 3-1/2" and 2-7/8" tubing at 2400 hours. Finished off-loading tubing. Made up 3-1/2" mule shoe, one joint of 3-1/2" tubing, X-nipple, one joint of 3-1/2" tubing, permanent packer seal assembly with chemical injection mandrel, and hooked up Camco dual encapsulated tubing. Ran 3-1/2" tubing to 3-1/2" blast joints. Blast joints had all bad threads. Sent blast joints to beach to be re-cut. Lost 14 hours. Continued running completion equipment at 2400 hours. ~'~ --~ UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. (J. , _ LEASE ,,. _ DATE , , ,,, ,, 11/16/87 11/17/87 11/18/87 11/19/87 11/20/87 11/21/87 11/22/87 11/23/87 11/24/87 TBUS E.T.D. 10,370' G-30 McArthur River Field WELL NO ...... FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Continued running dual 3-1/2" X 2-7/8" production equipment with dual chemical injection equipment at 2400 hours. Continued running dual 3-1/2" X 2-7/8" completion with dual chemical injection line. Engaged permanent packer and sheared off latch. Landed tubing as follows: 3-1/2 mule shoe at 10,059', X-nipple at 10,030', Otis internal chemical injection mandrel at 9971', X-A sleeve at 9932', Baker 3-1/2" blast joints from 9902' - 9579', Otis dual packer at 9446', X-A sleeve at 9411', gas lift mandrels from 9374' - 2495', ball valve landing nipple at 337'. Short string mule shoe at 9469', X-nipple at 9466', Otis internal chemical injection mandrel at 9437', X-A sleeve at 9402', gas lift valves from 9307' - 2465', ball valve landing nipple at 304'. Pressure tested control lines and checked for packer communication. Set packer with 3100 psi. Left "PX" plug in X-A sleeve at 9932' until hole equalizes. Re-ran 3-1/2" dummy valve at 337' at 2400 hours. Installed BPV's in tubing hangers. Nippled down BOPE and nippled up tree, tested tree to 5000 psi. Turned wellover to production at 0700 hours. Pulled BPV's and put well on gas lift. Load out rental equipment. At 1100 psi on 9-5/8" casing, 9-5/8" X 13-3/8" annulus had 1100 psi. Bled off both strings and attempted to re-energize secondary packoff. Put 1380 psi on 9-5/8" casing and still had slight blow to 13-3/8" casing. Bled down both strings and readied rig to nipple up BOPE at 2400 hours. Set rotary table and built floor. Installed both BPV and nippled down tree. Nippled up BOPE and tested. Rigged up wireline. With 3-1/2" plug in place at 9932', pulled dummy ball valve at 337'. Opened "XA" sleeve at 9411'. Circulated 280 barrels of 64 pcf fluid down long string taking returns to production. Well stable. Worked dual hydraulic packer free with 40,000#. Well stable. Pulled 3-1/2" X 2-7/8" completion assembly at 2400 hours. Continued pulling 3-1/2" X 2-7/8" completion assembly at 2400 hours. Finished pulling dual completion assembly. RIH with 9-5/8" RBP and RITS in tandem. Set RBP-at 4515' Set RTTS at 4382' and tested between tools to 2500 psi. Teste~ casing to surface to 2500 psi. Tripped for open ended drill pipe. Spotted 19 sacks of 20 - 40 mesh sand on top of RBP. Tagged sand at 4470'. Removed BOPE and found 12 - 3000 psi primary packoff not energized, upper snap ring missing and 12" X 9-5/8" secondary packoff deteriorated badly. The 9-5/8" casing stub had drill pipe wear. Energized primary packoff and installed top snap ring. Installed new DCB spool. Energized and tested secondary packoff' to 2500 psi. Nippled up BOPE at 2400 hours. Tested BOPE. Reversed out sand and recovered RBP. Welded standoffs to blast joints to hold chemical line clamps. Waiting on wireline tools to recover clamps left in hole. RIH with slickline at 2400 hours. Continued to RIH with 4" OD 4 prong internal wire grab and 8.37" OD gauge ring to top of 7" liner at 9785'. POOH, no recovery. RIH with 4 prong internal grab with 5.9" OD gauge ring to 9971'. POOH and recovered one band. Re-ran wireline tools to 9971'. POOH and recovered 6 bands. Re-ran wireline tools to 9971' Worked tool and sheared-off. POOH with wireline. Fished and recovered wireline tools and 7 bands. Total of 14 bands recovered. Installed 3-1/2" X 5" VBR and tested. Off-loaded 3-1/2" drill pipe. Pick up fishing tools on drill pipe and RIH at 2400 hours. Continued to RIH with 6" OD finger junk basket on drill pipe. Pumped 35 barrels of hi-vis pill and worked junk basket at 9965'. POH and had no recovery. RIH to retrieve Otis ratch-a-latch tool from perm packer at 9980' DPM. Rotated off ratch-a-latch. Sent retrieving tool into shop for machine work. Re-ran retrieving tool and engaged ratch-a-latch at 9980'. Rotated off and POH at 2400 hours. IJNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. LEASE TBOS G-30 McArthur River Field WELL NO FIELD DATE 11/25/87 11/26/87 11/27/87 11/28/87 11/29/87 11/30/87 01/04/88 1/05/88 1/06/88 1/07/88 E.T.D. 10,370 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Continued to POOH with ratch-a-latch assembly, recovered 13 bands on assembly. RIH with 2-7/8" tubing tail on drill pipe and tagged ETD at 10,370'. Tripped for Otis seal assembly. Tagged perm packer and tested seals at 1500 psi. POOH laying down drill pipe at 2400 hours. Continued laying down drill pipe. Pulled wear bushing and installed test plug. Installed dual rams in BOPE and tested doors and hydril at 1500 psi. Removed test plug. Prep to run production equipment at 2400 hours. RIH with dual gas lift production assembly. Latched into Otis 7" perm packer and sheared off PBR with 20,0009. Spaced out and installed dual hangers. Completion included dual chemical injection lines. Long string mule shoe at 10,058', chemical injection mandrel at 9969', hydraulic packer at 9444' and ball valve at 336'. Short string mule shoe at 9466', hydraulic packer at 9444' and ball valve at 303'. Rigged up wireline and pulled dummy ball valve from long string. Pressured up long string and set hydraulic packer. Retrieved PX plug from X nipple. Re-ran dummy ball valve. Tested packers by pumping down both strings with no returns. Installed BPV's in hangers and nippled down BOPE. Installed tree and tested to 5000 psi. Turned well over to production at 2400 hours, 11/27/87. Rigged down equipment and readied rig for move to leg 93. Moved equipment and began rigging up on leg ~3. Moved equipment and began rigging up over G-36. .Continued to demobilize rigs. Rigged up wireline on G-30 long string. Pulled ball valve from 336'. Rigged up coiled tubing unit and tested equipment to 5000 psi. RIH and tagged fill at 10,362' DIL. Washed to ETD at 10,370' with 6% KCL with 1.5 PPB HEC at 1.75 BPM at 4000 psi. CBU at 2400 hours. Continue to CBU. POOH and changed jetting tool. RIH to ETD @ 10,370' DIL with no signs of fill. POOH washing each GLM. Rigged down C.T.U. Wait on boat to bring out Gearhart electric line unit. Received Gearhart unit @ 0530 hrs. RU same. RIH and tagged ETD @ 10,364' DIL correlated with GR/CCL. Begin reperforating HB 3 & 4 from 10,364' to 10,230' DIL with 2.50" O.D., 0° phasing, 16 gm, 4 spf through tubing guns. Continued to reperforate Hemlock benches 3 & 4 f/10,364' - 10,230'. Bench 1 f/10,058 - 10,088' with 2.50 "O.D., 0° phasing, 16 gm, 4 spf through tubing guns. Returned well to production @ 1200 hrs. RR and crews @ 1400 hrs, 1/7/88. 3-1/2", 9.2~.,.. N-8.0, L.on9 Str. i..ng Tubin9 Detail From To Length Jts De~ription 10058.16 10057.66 10057.66 10028.96 10028.96 10027.91 10027.91 9997.61 9997.61 9992.11 9992.11 9978.71 9978.71 9975.26 9975.26 9969.36 9969.36 9965.24 9965.24 9934.18 9934.18 9930.10 9930.10 9900.79 9900.79 9586.92 9586.92 9577.28 .50 28.70 1.05 30.30 5.30 13.40 3.45 5.90 4.12 31.06 4.08 29.31 313.87 9.64 10~ 10 3-1/2" Mule Shoe 2-1/2" FL-45 Tbg. Otis 3-1/2" "X" Nipple 3-1/2" FL-45 Tbg. 3-1/2" N-80 Butt Ext. Otis Pbr W/ Ratch a Latch Assy Otis Pbr Ext W/X-Over Camco Chem Inj Mandrel 3-1/2 N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt Otis 3-1/2" "XA" Sliding Sleeve 3-1/2" N-80 Butt Baker 3-1/2" Blast Jts (16-20'long) Baker 3-1/2" Blast Jts (1-10'long) UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. LEASE TBUS G-30 LS McArthur River Field WELL NO.. FIELD.. DATE 90398N ( E.T.D. From 9454.16 9444.51 9413.94 9409.94 9378.66 9372.16 9342.19 9335.70 9306.06 9299.96 9178.43 9173.25 9081.69 9075.15 8709.76 8703.20 8645.17 8640.08 8580.24 8576.12 8361.77 8356.69 8235.71 8229.17 8225.11 8045.11 8039.03 7859.08 7852.83 7640.01 7633.46 7181.05 7174.87 7169.54 7018.47 7014.37 6922.64 6916.14 6057.02 6050.52 5106.13 5100.87 4857.87 4851.32 3665.61 3659.11 3024.74 3020.64 2501.24 2494.74 2344.14 2338.89 2187.23 2182.12 1999.76 1994.46 1782.39 1777.09 1626.55 1621.30 1468.69 1463.54 1310.15 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS TO 9444.51 9413.94 9409.94 9378.66 9372.16 9342.19 9335.70 9306.06 9299.96 9178.43 9173.25 9081.69 9075.15 8709.76 8703.20 8645.17 8640.08 8580.24 8576.12 8361.77 8356.69 8235.71 8229.17 8225.11 8045.11 8039.03 7859.08 7852.83 7640.01 7633.46 7181.05 7174.87 7169.54 7018.47 7014.37 6922.64 6916.14 6057.02 6050.52 5106.13 5100.87 4857.87 4851.32 3665.61 3659.11 3024.74 3020.64 2501.24 2494.74 2344.14 2338.89 2187.23 2182.12 1999.76 1994.46 1782.39 1777.09 1626.55 1621.30 1468.69 1463.54 1310.15 1305.02 Length JtS Decripti, on 9.65 30.57 1 4.00 31.28 1 6.50 29.97 1 6.49 29.64 1 6.10 121.53 4 5.18 91.56 3 6.54 365.39 12 6.56 58.03 2 5.09 59.84 2 4.12 214.35 7 5.08 120.98 4 6.54 4.06 180.00 6 6.08 179.95 7 6.25 212.82 7 6.55 452.41 15 6.18 5.33 151.07 5 4.10 91.73 3 6.50 859.12 28 6.50 944.39 31 5.26 243.00 8 6.55 1185.71 39 6.50 634.37 21 4.10 519.40 17 6.50 150.60 5 5.25 151.66 5 5.11 182.36 6 5.30 212.07 7 5.30 150.54 5 5.25 152.61 5 5.15 153.39 5 5.13 Otis 9-5/8" RDH Pkr. 1 Jt 3-1/2" N-80 Butt Otis 3-1/2" "XA" Sleeve 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3.1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3'1/2" N-80 Butt Tbg Pup Jt. 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jr. 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt. 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jr. 3-1/2" N-80 Butt Camco GLM 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt 3-1/2" N-80 Butt 3-1/2" N-80 Butt Tbg Pup Jt LEASE DATE #0398N ( ,,.-% UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. TBUS G-30 LS McArthur River Field WELL NO. FIELD E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS F rom To 1305.02 1217.37 1217.37 1212.11 1212.11 1093.64 1093.64 1088.32 1088.32 813.44 813.44 808.26 808.26 563.78 563.78 558.48 558.48 466.44 466.44 461.25 461.25 338.94 338.94 336.19 336.19 59.82 59.82 55.60 55.60 51.40 51.40 47.15 47.15 43.00 43.00 42.00 42.00 0 L. ength Jt's Decriptio~ 87.65 3 3-1/2" N-80 Butt 5.26 3-1/2" N-80 Butt Tbg Pup Jt 118.47 4 3-1/2" N-80 Butt 5.32 3-1/2" N-80 Butt Tbg Pup Jt 274.88 9 3-1/2" N-80 Butt 5.18 3-1/2" N-80 Butt Tbg Pup Jt 244.48 8 3-1/2" N-80 Butt 5.30 3-1/2" N-80 Butt Tbg Pup Jt 92.04 3 3-1/2" N-80 Butt 5.19 3-1/2" N-80 Butt Tbg Pup Jt 122.31 4 3-1/2" N-80 Butt 2.75 Otis 3-1/2" Ball Valve Nipple 276.37 9 3-1/2" N-80 Butt 4.22 3-1/2" N-80 Butt Tbg Pup Jt 4.20 3-1/2" N-80 Butt Tbg Pup Jt 4.25 3-1/2" N-80 Butt Tbg Pup Jt 4.15 3-1/2" N-80 Butt Tbg Pup Jt 1.00 Camron Dual Tbg Hanger 42.00 Landed Below Zero 2-7/8", 6.4~, N-80, Buttress 9466.34 9465.54 .80 9465.54 9464.14 1.40 9464.14 9454.16 9.98 9454.16 9444.51 9.65 9444.51 9435.31 9.20 9435.31 9403.69 31.62 9403.69 9399.64 4.05 9399.64 9305.06 94.58 9305.06 9298.51 6.55 9298.51 9083.75 214.76 9083.75 9077.87 5.88 9077.87 8707.55 370.32 8707.55 8702.27 5.28 8702.27 8696.15 6.12 8696.15 8363.21 332.94 8363.21 8356.60 6.61 8356.60 8204.63 151.97 8204.63 8198.74 5.89 8198.74 7643.08 555.66 7643.08 7637.39 5.69 7637.39 7177.03 460.36 7177.03 7170.53 6.50 7170.53 6919.86 250.67 6919.86 6915.94 3.92 6915.94 6461.60 454.34 6461.60 6456.40 5.20 6456.40 6217.25 239.15 6217.25 6211.93 5.32 6211.93 6028.44 183.49 6028.44 6021.84 6.60 6021.84 5626.33 395.51 5626.33 5621.33 5.00 5621.33 '5323.23 298.10 5323.23 5318.18 5.05 5318.18 4828.38 489.80 4828.38 4821.78 6.60 4821.78 4702.55 119.23 4702.55 4696.45 6.10 4696.45 3639.57 1056.88 Short string_Tubing Detail 1 3 7 12 11 5 18 15 8 15 8 6 13 10 16 4 35 Mule Shoe Otis 'XN' nipple 2-7/8" N-80 Butt. tbg. pup jt. Otis 9-5/8" R.D.H. Packer Camco Chemical Injection Mandrel 2-7/8" N-80 Butt. Otis 2-7/8" "XA" Slidding Sleeve 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 11 I! I! I1 1! I1 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" n-80 Butt. 2-7/8" Butt. tgb. pup jt. 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-8- Butt. pup jt. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg pup jt. 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. LEASE DATE TBUS G-30 LS McArthur River Field WELL NO FIELD E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 2-7/8", 6.4~, N-80, Buttress Short Str_ing Tubing Detail From To Length JtS Decription_ 3639.57 3632.92 6.65 3632.92 3425.67 207.25 3425.67 3420.59 5.08 3420.59 2689.81 730.78 2689.81 2684.68 5.13 2684.68 2471.13 213.55 2471.13 2464.53 6.60 2464.13 310.98 2153.55 310.98 305.69 5.29 305.69 303.39 2.30 303.39 56.70 246.69 56.70 46.52 10.18 46.52 45.40 1.12 45.40 43.00 2.40 43.00 42.00 1.00 42.00 0 42.00 24 69 Camco Glm. 2-7/8" N-80 Butt. 2-7/8 N-80 Butt. tbg pup jt. 2-7/8 N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" N-80 Butt. Camco Glm. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. Otis Ball Valve Nipple. 2-7/8" N-80 Butt. 2-7/8" N-80 Butt. tbg. pup jt. 2-7/8" X 3-1/2" N-80 Butt. X-over 3-1/2" N-80 Butt. tbg. pup jt. Camco duel tbg hanger 3-1/2" Butt. X 3-1/2" 8 R Landed below zero Note: There is 3/8" Incapsilated tbg running f/ tbg hanger to chemical inj. mandrel. The 3/8" tbg is clamped to 2-7/8" short string w/Camco Clamps. There is 1/4" stainless tbg. f/ tbg hanger to Otis Ball Valve. ALAS , OIL AND GAS CONSERVATION COM .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 I~ Amend order [] Perforate~] Other G~ 2. Name of Operator Union Oil Company of California 3. Address P.O. Box 190247, Anchorage, Alaska 99519-0247 4. Location of well at surface 1876'N-1378'W f/SE Cr., Sec 29, T9N, Ri3W, SM At top of productive interval 2511'S & 2173'E of Surface Location Ateffective depth 3325'S & 2404'E of Surface Location Attotaldepth 3377'S & 2414'E of Surface Location 5. Datum elevation(DF or KB) 99' RT to MSL 6. UnitorProperty name Trading Bay Unit 7. Well number , G-30 8. Permit number 69-47 9. APl number 50-- 133-20187 10. Pool McArthur River Field feet 11. Present well condition summary Total depth: measured 11,451 feet true vertical 10,328 feet Effective depth: measured 11,345 feet true vertical 10,250 feet Casing Length Size Structural 365 ' 26" Conductor 520 ' 17-3/4" Surface 4779' 13-3/8" Intermediate 9866' 9-5/8" Production 1659.' 7" Liner Plugs (measured) Junk (measured) Cemented Measured depth A~;Oh~Verticaldepth Driven 365' 365' 750 SX 520' 520' 2200 SX 4779' 4486' 1800 SX 9866' 8950' 1000 SX 11,444' 10,323' Perforation depth: measured10,575'-10,622,; 10,475'-10,535'; 10,300'-10,390';10,230'-10,280,; 10,058'-10,088'; 9824'-9892'; 9702'-9766'; 9660'.-.9681'; 9588'-9610' true vertical 9575'-9616'; 9488'-9540'; 9336'-9105'; 9274'-9318'; 9120'-9147,; 8911'-8972'; 8802'-8860'; 8765'-8774'; 8700'-8711' Tubing (size, grade and measured depth) SS: ~3~-1/2,,; 9.2#, N~80 @ 333~ & 2~7/8'.'.~ 6.4#, ~-8:0 @.9427 LS: 3-1/2", 9.2#, N-80.@ 10,043' Packers and SSSV (type and measured depth) Otis "XL" Ball Valve @ 303'; Otis RDH @ 9410'; Otis "WO" perm. Pkr ¢ 10:4~'~ O~S pe_~m Pkr ~ 10,036' 12.Attachments Description summary of proposal [~ Detailed operations program [] BOP sketch [~ 13. Estimated date for commencing operation 5-10-87 14. If proposal was verbally approved Name of approver Date approved 15.1 hereby certify that the foregoing is true and~?~{.~ct to the best of my knowledge Signed /~,~. ~/__~_..~ J~itle Environmental Engineer ~Roy Roberts C%mmission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearance I Date 5/4/87 No. Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate TBUS G-30 PROCEDURE le e o e Se e e Be e 10. 11. 12. Rig up over TBUS G-30, leg 2 slot 44. Kill well observing 9-5/8" x 13-3/8" annulus. Set BPV, remove tree, install and test BOPE. Pull and lay down dual tubing strings (SS: 3-1/2" to 333' 2-7/8" to · , 9,427'; LS: 3-1/2" to 10,043.) Mill over and recover Otis permanent packers at 10,020' and 10,400'. Correct 9-5/8" x 13-3/8" annulus pressure as follows: Test casing to 2500 psi. If casing tests, attempt to pump down 9-5/8" x 13-3/8" annulus establishing a rate. Attempt to pump cement from surface to casing shoe. If casing does not test, locate hole in casing. If hole is below 13-3/8" casing shoe, squeeze as required. If hole is above 13-3/8" casing shoe, attempt to circulate cement down 9-5/8" casing and up the 9-5/8" x 13-3/8" annulus to surface. Clean out and test squeezes and casing if needed. Cement squeeze existing perfs 10,575'-10,622' 10,475'-10 535' 10,300'-10,390', 10,230'-10,280' 10,058'-10,088' and 9702'-9766' ' Perforate the following Hemlock and "G" zone sands: 10,340'-10,350', 10,250'-10,260' and 10,068'-10,078' stimulate sands if required.) 9730'-9740' . ( Fracture Perforate the following "G" zone sands with tubing conveyed guns: 9824'-9842' 9702'-9766' 9660'-9681' and 9588'-9610' Run dual 3-1/2" tubing string completion separating "G" zone and Hemlock sands. Remove BOPE, install and test tree. Put well on production. JCL:tjp 0247N 4-29-87 · .5 ANGLED FILL UP LIHE . . ::- - ..~ , -:"."%" .':': ..... ~ .... . ~ HYDRIL · . :..( ..:~, . r ...: " ' : - PIPE ~A~ . ..- ~: .' .: - : ~ ~: · -- HYDRAULIG ' ,~ .. ~~ ."{ ,". ~. "%- :4¥ :..,~: ~.~. ~ / '~, TO MUD PUMP~ ~ CEMEHT '"'~T ~ ~ ~' '~'~ ~' ~" . ?::...: :.. . ~. ' . ,:: ' ~::' '., -:'~:':'?: NOmES' 1, MYDRAULIO VA~V[~ ' WNLL NAARS: _ AUTOMATICALLY WHEN ..... RIG CONTRACTOR: DIVERTER IS CLOSED. RIG: 2 FLE~ ~ ~'/'~ ~ ~ ~: "~ STACK ~ee/m= Ci'IOI(E' L/NE ~lZ~ & ~SP: ..... ~,~ ~ , ~H= DIS~'~ D~ILL~;'{G S~PE~i['~T~HD !1 :.l A£v GATE. :i_% E J,',.~_JJJ~.-[q. :t , ; I' I'. · · ., ! · DEPT. APPROVAL -_ 5.1 "'"'-- "-""" OR I ii , ~ ......... ~:: - ~ UNION OIL COMPANY or CALIFORNIA ~ .~- 'K~,'' STATE OF ALASKA ~I . ALAS OIL AND GAS CONSERVATION COM .51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of ~per~or 5. Datum elevation(DF or KB) Union uzl company of California (UNOCAL) 99' above HSL 3. Address 6. UnitorProperty name / P.0. Box 190247, Anch, Ak., 99519-0247 Trading Bay Unit 4. Location of wellatsurface Conductor #44, 1876' N & 1378' N from SE Corner, Section 29, T9N, R13W, SH Attop ofproductiveinterval 2965' S & 2325' E of Surface Location At effective depth At total depth 3377' S & 2414' E. of Surface Locatic 7. Wellnumber G-30L 8. Approval number 69-47 9. APl number 50-- 133-20187 10. Pool n Hemlock Pool 11. Present well condition summary Total depth: measured true vertical 11451 feet Plugs (measured) 10328 feet Effective depth: measured 11345 feet Junk (measured) true vertical 10250 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 520' 17 3/4" 750 SX 520' 520' Surface 4779' 13 3/8" 2000 SX BO & 4779' 4486' Intermediate 200 SX "G" Production 9866' 9 5/8" 850 SX BO & 9866' 8950' 1659' 7" 950 sx CFR2 11444' 10323' Liner Perforation depth: measured 10300-10390'; 10230-10280'; 10058-10088'; 10475-10535'; 10575-10585'; I I I l 9588-9610'; 9660-9681 ; 9702-9766 ; 9824-9892 ; 10575110622 . true vertical 9336-9105'; 9274-9318'; 9120-9147'; 9488-9540'; 9575-9583'; ~bing (size, gr~E~7rfll'~a~r~J~t~7~'; 8802-8860'; 8911-8972'i 9575-9616'. 1/2", 9.2#, N-80 ~ 10412 Packers and SSSV (type and measured depth) Otis 7" Perm Pkr ~ 10036.43'; Otis 7" "W0" Perm .............. ~ ..... K E L-F I-V E-t/ -- 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) OCT 2 i 1986; Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Anchora.qe Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 157 0 175 820 100 462 0 753 820 120 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Ro~D. Roberts Titl~Environmental Engineer Form 10-404 Rev. 12-1-85 Submit in Duplicate #14. DAILY REPORT OF WELL OPERATIONS 10/8/86 RU Schlumberger and tag fill at 10357' DIL. Perforate 10298-10328' CBL, (10300-10330' DIL). 10/9/86 Perforate 10328-10353' CBL, (10330-10355' DIL). Perforate 10228-10278' CBL, (10230-10280' DIL) and 10056-10086' CBL (10058-10088' DIL). RD Schlumberger. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM oSION APPLICATION FOR SUNDRY APPROVALS feet 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing C Amend order [] Perforate ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) 99' above NSL 3. A~.r~s.s Box 190247, Anch, Ak., 99519-0247 6. U~~e~yn~t 4. Location of well at surface 7. Well number Conductor #44, 1876' N & 1378' N from G-30L At~pCo~uct~i~q~t~4~Ra129, T9N, R13W, SM 8. Permit number 2965' S & 2325' E of Surface Location 69-47 At effective depth 9. APl number 50-- 133-20187 At total depth 10. Pool 3377' S & 2414' E. of Surface Location Hemlock Pool 11. Present well condition summary Total depth: measured 11451 feet Plugs (measured) k E C E ~ V ~ true vertical 10328 feet Effective depth: measured 11345 feet Junk (measured) OCT 0 3 1.986 true vertical 10250 feet Al~sk~ 0ii & Gas Cons. (;0r~n~issi0n Casing Length Size Cemented Measured depth Anch°r~uee Vertical depth Structural Conductor 520' 17 3/4" 750 sx 520' 520 ' Surface 4779' 13 3/8" 2000 SX BO & 4779' 4486' 200 SX "G" Intermediate 9866' 9 5/8" 850 SX BO & 9866' 8950' " Production 1659' 7" 950 sx CFR2 11444' 10323' Liner Perforation depth: measured 10300-10390'; 10230-10280'; 10058-10088'; 10475-10535'; 10575 10585'; ! ! ! 9588-9610'; 9660-9681 ; 9702-9766 ; 9824-9892 ; 10575-10622 true vertical 9336-9105'; 9274-9318'; 9120-9147'; 9488-9540'; 9575-9583'; 8700-8711 ': 8765-8774'; 8802-8860'; 8911-8972' i 9575-9616'. Tubing (size, grace and measufec[ depth} 3 1/2", 9.2#, N-80 (~ 10412 Packers and SSSV (type and measured depth) Otis 7" Perm Pkr ~' 10036.43'; Otis 7" "W0" Perm Pkr at [040~.69'; Otis "XL" Ball Valve $ 302.63' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] See Attached 13. Estimated date for commencing operation 10/6/86 14. If proposal was verbally approved Name of approver Date approved 15. I hereby cer,t,ify that the foregoing is true and correct to the best of my knowledge SigneU , D, rt$ Title Environmental Engineer Date 10/2/8(; Commission Use Only Conditions of approval Notify commission so representative may witness I ApprovalNo. ~,_~,/ [] Plug integrity [] BOP Test [] Location clearance ' ~:~ ~:~':; ~ ........... by order of ~'~ ~ Commissioner the commission Date Approved by ..... ~, Form 10-403 Rev 12-1-85 Submit in triplicate #12. Description Summary of Proposal G-30L RROCEDURE: 1. R.U. slickline unit and pull ball valve. 2. Run 2.25 gauge ring to 10,400'. (Isolation Racker.) 3. R.U. electric line unit. 4. Rerforate Benches l, 3 and 4 (10058-10088'; 10230-10280'; 10300-10390') at 4 HRF, shoot all perforations under drawdown conditions. 5. Rig down and return well to production. December 1, 1977 ADMIN I ST RAT IVE APPROVAL NO. 80.2.0 Re: Applica~ of Union Oil ~y of Cali~, Trading Bay .. ~ w~ll as part .of the pressu~ maintenance project app-~ District L: d Union Oil Cxmpany of California P. O. Box 6247 Anchorage, Alaska 99502 O~ No~a~ber 30, 1977, the ref~ application was received which stated that the proposed well would urovide a crestal final withdrawal point ~%ich will result in addit/onal Hemlock recovery. .The Oil and Gas ~rvaticn ~ttee hereby authorizes ~he drilling.. and (xx~letic~ of t]%e referenced ~11 pursuant to Rule 5 of the Co~servatic~ ~ No. 80. Yours very truly, ~., Union Oil and l~'~ ~ Division: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union October 3, 1984 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission ~OO1Rorcupine Drive Anchorage, Ak. 99502 Dear Mr. Chatterton: SUNDRY NOTICE - GRAYLING PLATFORM Attached, for your information and file, are subsequent Sundry Notices on Union operated wells G-7 and G-~OL. Very truly yours, Lawrence 0. Cutting Environmental Technician LOC:owl Attachment RECEIVED OCT 0 ~ 1~14 Alaska Oil & Gas Cons. Commission Anchorage '~i' STATE OF ALASKA ALA ,A OIL AND GAS CONSERVATIOR ~,OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name O,L~ro~r 0IL COMPANY OF CALIFORNIA 7. Per~i~N~7 - 8. APl b r 3. Address PO a0x 6247 ANCHORAGE AK 99502 50- ~;~-~:~0187 9. uni~AL~S~l~a~Y UNIT 4. Location of Well Conductor #44: 1,876'N + 1,378'W from SE corner Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 99' Above MSL 12. I 6 . Lease Designation and Serial No. ADL 18730 1°' W~B~bl~..30L 11. Field and Pool HcARTHUR 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 [] RE Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were reperforated on August 10, 1984: Bench Interval i 10,058' to 10,088' 3 10,230' to 10,280' 4 10,300' to 10,390' RECEIVED OCT 0 klasl<a Oii & 6~s Ct, ns, commission Ancn~rs~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~~)~' ~ ,~l~l-itle ENVIRONMENTAL TECHNICIAN The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~'i STATE OF ALASKA ( ALAS ,, OIL AND GAS CONSERVATiON OMMISSION SUNDRY NOTICES AND REPORTS ON WmLL$ 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator UNION OIL COHPANY OF CALIFORNIA 3. Address P.O. BOX 6247, ANCHORAGE, AK 99.502 4. Location of Well Conductor #44: 1,876'N + 1,378'W from SE corner Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 95)' Above MSL 12. I 6 . Lease Designation and Serial No. ADL 18730 7. Permit No. 69-47 8. APl Number 5o_133-20187 9. Unit or Lease Name TRADING BAY UNIT 10. Well Number TBUS G-30L 11. Field and Pool OTHER [] MCARTHUR RIVER FIELD Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEOUENT RERORT OF' 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 (Submit in Triplicate) (Submit in Duplicate) Re Perforate IX] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to reperforate the following: Bench 1 4 Interval 10,058' to 10,088' 10,230' to 10,280' 10,300' to 10,390' RECEIVED Subsequent Work Reported .o- Form No./~Dat~d L~/~f~ 14. I hereby cer~;ffy that the foregoing is true and correct to the best of my knowledge. Signed Title JUL 3 11984 Alaska Oil & Gas Cons. C0mmissi Anchorage The space below for Commission use Conditions of Approval, if any: District Enqineer Date 7/26/84 ORIG'NA[ SI;NEll 8Y IOH~IE C. SMITI Approved by COMMISSIONER Form 10-403 APproved Copy . "' Returned By Order of the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALA~~ '~""~,L AND GAS CONSERVATIO ' .,~ IMISSION SUNDR NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 1~ OTHER [] 2. Name of Operator 7. Permit No69_47 UNION 0IL COMPANY OF CALIFORNIA 3. Address 8. APl Number 909 W. 9TH AVE., P. 0. BOX 6247, ANCHORAGE, AK 99502 50-133-20187 4. Location of Well Cond. #44: 1876' N & .1378' W from SE corner, Sec. 29, T9N, RI'3W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 99' RT above MSL [6. Lea~DD[~si~n~J~n0and Serial N o. 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number TBUS G-30L 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 [] Re Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The' follOwing intervals were reperforated 10/82' 10,058' 10,088' 10,230' - 10,280' 10,300' - 10,390' RECEIVED OCT 2 ? J982 Alaska Oil & Gas Cons. Commission Anchorage Signed ~~ --' Title District Engineer The space be,ow for Commiss~'~ u~. Case Date 10/19/82 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 E)u'plicate ~' .~ ~. STATEOF ALASKA ALA~.., toiL AND GAS CONSERVATIOII~ ~C~MMISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WE LL )(-I OTHER [] 2. Name of Operator UN[ON 0IL COMPANY OF CAL[FORN[A 3. Address. 909 W. 9TH, P. 0. BOX 6247, ANCHORAGE, AK Location of Well Cond #44' 1876' N & 1378' W from SE corner, Sec. 29, T9N, R13W, S.~J. 99502 5. Elevation in feet (indicate KB, DF, etc.) 99' RT above MSL 6. Lease Designation and Serial No. ADL 1873O 12. 7. Permit No. 69-47 8. APl Number 50- 50-133-20187 9. Unit or Lease Name Trading Ray Unit 10. Well Number TBUS G-30L 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) RePerforate [~ Alter Casing ~-] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to reperforate the following 'intervals: 10,058' - 10,088' 10,230'- 10,280' 10,300' - 10,390' $~bsec~,zerJ: Wm:k Y~epo~te& 14 I hereby cer, ti~r~/~ll~rtC'the forego ng is true and correct to the best of my knowledge. · .! ~. ¢. lq. Corse The space below for Commission use Date 10/14/82 Conditions of Approval, if any: Approved by Form 10~403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate [ ' STATE OF ALASKA (~_, ALASK .)IL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER DRILLING WELL [] COMPLETED WELL i-~ 2. Name of Operator Union 0il Company of California 3. Address P. 0. Box 6247, Anchorage, AK 99502 4. Location of Well Cond. #44- 1876' N and 1378' W. from SE corner, Sec. 29, 7. Permit No. 69-47 8. APl Number 50- 133-20187 9. Unit or Lease Name Trading Bay Unit T9N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 99' RT above HSL 6. Lease Designation and Serial No. ADL 18730 10. Well Number · TBUS G-30L 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Rep..o_...rtFor Othi~r Da'~ NOTICE OF INTENTION TO: ~ SUBSEQUENT REPORTO (Submit in Triplicate) (S?_b_.~ Perforate [] Alter Casing [] Perforations F~l A!tering 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 February, 1981. 10058 - 10088 10230 - 10280 10300 -. 10390 Bench 1 Bench 3 Bench 4 RECEIVED FEB 1 1 1981 Alaska 0il & Gas Cons. Commission A~chorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~L"~_....~2~ Title District Fngineer The space~lo~ .for(~l~e~ission use Date 2/!0/81 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 Submit *'Intentions" in Triplicate REV. 1-10-73 & "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 50-133-20187 LEASE DESIGNATION AND SERIAL NO. ADL 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME x. O,L r;3 GAS r-I WELLIA/! WELL L.--J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Union Oil Company of California Trading Bay Unit 3. ADDRESS OF'OPERATOR 9. WELL NO. P.O. Box 6247, Anchorage, AK 99502 TBUS G-30L 4. LOCATION OF WELL At surface Cond #44' 1876' N & 1378' W. from SE corner, Sec. 29, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT McAr'thur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, R13W, S.M. 12. PERMIT NO. 69-47 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING r'~ F RACTU R E T R EAT MU LTI PLE COMPEETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Reperf existinq intervals SUBSEQUENT REPORT OF-' WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I:)ertlnent cletells, and give pertinent dates, including estimated date of starting any proposed work. It is proposed to reperforate the following intervals- t0058 - 10088 10230 - 10280 10300 - 10390 Bench 1 Bench 3 Bench 4 RECEIVED jAN2219R! al & 6as Cons. Commission 16. I hereby certlfy~cthaj~l~e foregoing is true and correct SIGNED . L,. [-i. L,~OI- , TITLE District Enoineer DATE l'/20/R1 APPROVED BY CONDITIONS OF ~d~P-ROVAL, IF ~'~hTl~' T~ CG~,~I=SSJ0N See Instructions On Reverse Side DATE ~4pproved Copy Returned !1 Trading Bay Unit .?iC!,D McArthur River U?,iiON OIL CO. OF' CAL. I'- '--' i-O,-,h,l IA VVELL ~ZCO~D START 12/4/77 WELL NO, G-30 W.O.g~ DATE ' ' ~ Grayling Platform Leg Room #2 LOCA%I,.N Conductor #44 1876'N 1378"W of Sec~i_o.n 29..T9N,, R13W. S.M .... PEZMIT NO. 69-47 SEIIIAJ~ NO. ADL 18730 SHEET PAGE hlO~/ · COMP. PATE 1/f~78 CONTRACTOD, Par_ker RIG NO.~__ TYPF, UNIT National 1320 Diesel Electric ~.~ _._ DRILL ~' '~ 5" ~'lz ,'. DESCRIPTION S-135, G. E ~ ELF. VATIONS: V/ATEII DEI~I'it 12~'. ~ T. TO OCEAN FLOOtl ~224' T.D. 11451' MD TD T.V.D.__l~0328 R.T. TO MLLW 99' i)EVIATIO~ (,B.H.L.) 337_~4'E_of ~urface tl.T. TO DR[I,L DEC.~ lqq' R.T. TO~ PRODUCT~O~.~)E(/'K/ ~2_. 6,~ ~ .... _ . . COMPANY ENGINEER Watson. H~s. Westor THREAD Spiral We: A.S .L. Buttress GiRADE 17 3/4"1~312 wall 1' 9 5/8"{ 47&43_PjL_ .d J-55 N-80&P-110 DEPTH 520' 47.79' 9866' Buttress N-80 9785'to 11444' REMARKS Cmtd.w/2200 sgs w/~dditives Cmt~d w/1800 sxs w/additives ;5 Cmtd w/1000 sxs w/a~ditive~ ~ · PERFORATING ]RECORD 7/16/69i 10712-10728 11348 Production LWest Foreland Zone " 10828-10838 " " " " " - ~ " ' 10860-10875 "',, , ,, ,i ...... ,, "' ,, " 10883-10891' ' ..... ,, .... ,, .... , ,, ,,L ' "' 10895-10899 · "' " " " " S~z'd w/150 sxs 12/14~7~ , . -- " 10902-10914 ' ',,' i ,, ,, ,, ,, 7/18/69i 11078-11130 ' "" " ..... ~' ' " " " " 11179-11216 ' " .... '; ' " " " ...............3 "' " · 11264-11299 .... ,f ,, ,, ',,' ,, ' "' 9537-9563 " . ." '"G" Zonle Sqz'd,w/~200 Sl~XS ... " q588-9610 " " ~ " " Open ' " 9660-9681 " " " " " " Il Q 7(l?-Q7 f~f~ Il II 'II II' Il " qg24-qg57 " " " " " " 9~_7__~-__9892 " " ' " " ' " l, 9956--9q7117 Il ,1 ~ I ,, ,10omnCunablm to hrk dwn w/6O00omi 12/3/73~ ~Z/,.15/.'77 10418-10420 110695' ][soia~.ioi1. S ~. I Sql.'d w/i00'sxs 12/15/77 .... II ''lll ~ 0 ~__J=~ ..... !.o3952.. i ' ' ~ ____[j~~~ INITIAL PRODUCTION WELL t4._E3~D_A_S $ E 14 D~L Y i TYPE:. Dual 3½" C~I.W. CASING HEAD' 13' 3/8" S'.o.w'. x 12, 3000 psi Shaffer CASING HANGER:~ 12" Nominal w/2" S.E. outlets Model "KDS" CASING SPOOL: - TUBING HEAD: C.I.W. 12" 3000 psi X 10" 5000 psi "DCB" TUBING HANGER:-- I _Dual. l 3k"a "DCB" TUBING tIEAD TOP' 10" 5000 psi MASTER VALVES: Dual 3" Master & swab OIL. CO. OF' C;AL. Ii":O',qi',IIA SHZET A PAGr.i biO,_ Trading Bay Unit McAr thur River START WELL No..G-30 W.O. ~J~ DATE 12/4/77 COi.,.~Tt{7~CTOi% Parker LOCATION Grayling.Platform .keg Room #2 Conductor #44 1876'N 1378'W of Sect_ion 29 T9N, R13W, S.M. PERMIT NO. 69-47 SERI.AJ, NO ADL 18730 T.D.11451' MD TD T.V.D. 10328 _ DEVIATION (B.H.L.) 3377'S 241~'E of Burface COMPANY ENGINEER .Watson, Hess, Westor WEIGHT THREAD G~ADE COMP. DATE 115178 __ RIG NO. 54_ TYPE UNIT_Na_tional 1320 Diesel Elec~r_ic DR!I,LP1PEDESCRIPTION. 5, S-135, G, E ELEVA'flONS: WATER DE~I'it tLT. TO OCEAN FLOOR R.T. TO MLLW R.T. TO DR'[I,L DECK R.T. TO PRODUCTION DECK APPROVED: CASING ~ TUBING RECORD 125' +__224' 99' 193' 42.6' SIZE DEPTH PERFORATING RECORD 12/18/77 10575-10622 10670 Production J_Hemlock Bench #§ Oven ... " QR7R- qRq? "I" ___ "~" gonoh ~5 " 982&- 9R57 " " .... " " " '" " II Il " .q702- q766 _ " " G'~4__ " -- "' · 9660- 9681' '" " "G" Bench #3 " 12/19/77 9588- 9610 " " Reperf'd "G" Bench #2 " ,,, 1~ 4/78 10575-10585 " ' " Reperf'd Hemlock Bench #6 " 1/ 5/78 10475-10535' " " Hemlock Bench #5 " __ , ,_ ! · · I , ,, - ' ,, , INITIAL PRODUCTION / , , . W E_L_Lt/_E3ID_A__S S E ~4 DJ_~ Y TYPE: Dual 3½" C.I.W. CASING HEAD:__ 13 3/8" S.O.W. X i2" 3000 psi Shaffer CASING HANGER: 12" Nominal w/2" S.E. outlets Model ""KDS" CASING SPOOL: TUBING HEAD: C.I.W. 12" 3000 psi ~ 10" 5000 psi "DCB" TUBING HANGER: TUBh",IG tlEAD TOP: Dual 3M" "DCB" 2 10" 5000 psi MASTER VALVES: Dual 3" Master & swab CHRISTMAS 'Fi~I£E TOP CONN.: . 3½".. EUE 8 RD UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE ;40. LEASE TRADING BAY UNIT STATE WELL NO. TBUS G-30 FIELD TRADING BAY FIELD DATE 1 12/4/77 2 12/5/77 3 12/6/77 4 12/7/77 5 12/8/77 6 12/9/77 7 12/10/77 8 12/11/77 ETD 11444' TD 10621' ETD (Perm Pkr) 11444' TD 10621' ETD (Perm Pkr) 11444' TD 10621' ETD (Perm Pkr) 11444' TD 10621' ETD (Perm Pkr) 11444' TD 10621' ETD (Perm Pkr) 11444' TD 10621' ETD (Perm Pkr) 11444' TD 10621' ETD (Perm Pkr) 11444 ' TD 9902 ' ETD (TOF) DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS Before activation of Rig #54 an attempt was made to pull GLV from G-30LS w/ slick line unit and was unable to work tools below obstruction @ 3318'. Returned well to production. A!te completion of activation RU Dresser Atlas & ran perf gun in LS & couldn't get below 3318'. Filled 9 5/8" X 3½" annulus w/ 66#/cu.ft. W.O. fluid. Installed BPV & removed X-mas tree Installed & tested BOPE. RU to pull dual 3½" tbg strings & couldn't release Otis hyd pkr @ 9409'. While working tbg to 165,000# parted dual elevator bail. RD Weatherford & RU Camco. Completed pulling 9 GLV f/ 3½" short string tbg & closed all sleeves in GL mandrels. Tested tbg o.k. & opened CX sleeve @ 9377' above Otis dual hyd pkr @ 9406'. Circ out produced fluids in short string & conditioned WO fluid. RD Camco slickline unit. RU Dresser Atlas. Ran Dresser Atlas free point indicator on 3½" short string indicating tbg. free to dual hyd pkr @ 9409'. Pulled 150,000# to move tbg @ 9409' for free point. Ran DA 2 9/16" od tbg cutter & cut 3½" short string @ 9406'. Pulled & laid down 303 its plus 1 piece 3½" tbg (98,000# to move tbg off bottom). Pulled 160,000# on 3½" long string & released hyd pkr @ 9409'. Pulled seal assy free from perm pkr @ 10621' & circ bottoms up. Spotted 50 bbl of FIW w/ 25#/bbl Dril-S & 21#/bbl safe seal across "G" zone perfs 9588'-9977'. Pulled & laid down 3½" long string, incomplete. Pulled & laid down 341 jts of 3½" L.S. tbg. Changed rams in BOPE & tested to UOCO specs. Ran 5 7/8" od burnover shoe on 7' jr-of 5 3/4" washpipe on two 4 3/4" od drill collars & 1700' of 3½" DP. TIH picking up 5" od DP. While PU DP @ 4800' - broke high drum chain in drawworks. Wait on parts & replace brake pads. Repairing draww'orks. -. : Completed repairing drawworks. (total down time 75½ hrs). Continued running 5 7/8" burnover shoe, 7' of 5 3/4" washpipe, and two 4 3/4" DC on 1729' - 3½" DP. Finished picking up 5" DP ~ubbering every other joint and' RIH to Baker Model "F" perm~kr @ 10621' (10630'DPM). Burned over pkr in 13½ hrs & pipe torqued two times when pkr ~started moving down hole. PU & checked weight then chased pkr down to 11182' & pkr hung up. Circ'd bottoms up and POOH w/ DP. Rec~d 101 jts 5" DP & 17 jts 3½" DP w/ pin thread on last jt of 3½" DP pulled & jumped f/ box. Left in hole 5 7/8" od burnover shoe, 7' of 5 3/4" washpipe, 4 3/4" boot basket, 2-4 3/4" DC and 39 its. (1204') 3½" 13.30# Grade "E" DP. Total fish_1279.86' with top of fish @ 9902'. (117' inside 7" liner) UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT STATE WELL NO. TBUS G-30 FIELD TRADING BAY FIELD DATE 9 12/12/77 10 12/13/77 ll 12/14/77 12 12/15/77 13 12/16/77 ETD 11444 ' TD 11182 ' ETD (Junk) 11444 ' TD 11182 ' ETD (Junk) 11444 ' TD 10695 ' ETD (cmt ret) 11444' TD 10192' ETD (cmt ret) 11444 ' TD 10670' ETD (cmt) DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS Picked up 5 3/4" overshot w/ extension dressed w/ 4 3/4" mill control & 4 3/4" grapple, bumper sub & jars on 3½" X 5" DP. RIH to top of fish (3½" DP box) @ 9902'. Dressed & engaged fish in ½ hr. POOH & rec all of fish. No damage to tools except jumped box on top jt of 3½" DP. LD burnover and fishing tools. Ran 6" bit, 7" csg scrpr & three 4 3/4" DC on 3½" X 5" DP to perm pkr left @ 11182' & circ bottoms up. POOH. Temp switch charges from AFE #371443 to AFE #371444 @ 12:00 midnite 12/12/77. Commenced operations on AFE #371444 12:01 AM 12/13/77. RU Dresser Atlas logging unit & ran Compensated Neutron- 'Gamma Ray Log over zone of interest 10,700' - 9500'. Ran Log #2 Neutron-Lifetime Log 10700' - 9500'. Ran Log #3 Carbon Oxygen Log. Finished running DA C/O log #3 f/ 10700' to 9500'. RD logging unit. Charges ceased on AFE #371444 @ 6:00 AM 12/14/' Recommenced charges on AFE 371443 @ 6:00 AM 12/14/77, Ran 7" Howco cmt ret on W.L. & set @ 10695'. RD W.L. unit. Ran ret stinger on 3½" X 5" DP & stung into ret @ 10695'. Broke down West Foreland perfs 10712' - 11299' @ 2500 psi & pumped in @ 12 cu.ft./min & 2500 psi. Held 1375 psi after 10 min. w~ pump off. Squeezed for abandonment West Foreland perfs ~ °10712' - 11299' w/ 150 sx C1 "G" w/ .75% D-31, .3% D-13, .1% D-6 mixed @ ll6#/cu.ft, to a final pressure of 2600 psi after 10 min. w/ pump off. Pulled out of ret & dumped 10 cu.ft, cmt plug f/ 10695' to 10647'. POOH w/ DP. Charges ceased on AFE #371443 @ 12 mid 12/14/77. RecommenCe charges on AFE #371444 @ 12:01 AM 12/15/7.7. RU DA & perf 4 holes f/ 10418' to 10420' for WSO squeeze. Ran 7" Howco cmt ret on W.L. & set @ 10395'. -Ran stinger on 3½" X 5" DP & set in ret @ 10395'. Broke down sqz holes 10418' - 10420' @ 3450 psi & PI @ 4½ cu.ft./min. & 3450 psi. Mixed & pumped 100 sx C1 "G" w/ .75% D-31, .3% D-13 &. .1% D-6 mixed @ ll8#/cu, ft. thru perfs f/ 10418' - 10420' (Final Pressure).- Pulled out of ret & dumped 25 cu. ft.. cmt-on ret. POOH & RU DA. Perf 4 holes f/ 10215'~- 10217' for WSO sqz. Ran 7" Howco cmt ret on W.L. & set @ 10192'. Ran ~tinger on 3½" X 5" DP & set in ret @I0192' Broke down sqz holes 10215' - 10217' @ 4800 psi & PI @ 4cu.ft. min. & 3600 psi. ~-Mixed & pumPed 75 sx CL "G" w/ .75% D-31, .3% D-8 & .1% D-6 mixed @ ll8#/cu.ft, thru perfs f/ 10215' to 10217' (final pressure 500 psi). Pulled out of ret & dumped 20 cu.ft, cmt on ret. POOH. Ran 6" bit, two 5 7/8" boot baskets, & three 4 3/4" DC on 3½" X 5" DP to TOC @ 10%06. C.O. cmt f/ 10106' to 10150'. Drilled out WSO sqz cmt inside 7" liner f/ 10150' to cmt ret @ 10192'. Drilled ret & hard cmt across WSO perfs 10215' - 10217' & fell free to 10245'. Drilled cmt f/ 10245' to cmt ret @ 10395' & made bit trip. Drilled ret @ 10395' & found no cmt across WSO perfs 10418' - 10420'. Ret pushed free to 10439'. Drilled hard cmt f/ 10439'-10522' & fell free to 10610'. Drilled hard cmt f/ 10610' to 10670' (leaves 25' cmt plug on West Foreland abandonment ret @ 10695'). Circ hole clean & spotted 110 bbl of fresh FIW w/ 10#/bbl Dril-S & 18#/bbl KCL f/ 10670' - 8730'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT STATE WELL NO. TBUS G-30 FIELD TRADING BAY FIELD DATE 14 12/17/77 15 12/18/77 16 12/19/77 17 12/20/77 18 12/21/77 19 12/22/77 ETD 11444' TD 10670' ETD (cmt plug) 11444' TD 10670' ETD (cmt plug) 11444' TD 10020' ETD (perm pkr) 11444' TD 10020' ETD (perm pkr) 11444' TD 10020' ETD (perm pkr) 11444' TD 10020' ETD (perm pkr) DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS POOH. Ran 6" bit & 7" csg scrpr on 3½" X 5" DP to 10670'. Circ bottoms up & spotted 110 bbl fresh FIW w/ 18#/bbl Dril-S 18#/bbl Safe-Seal, & 18#/bbl KCL f/ 10670' - 8730' for perforating. POOH. Rigged up Dresser Atlas & ran Gamma Ray CBL signature log f/ 10670' to 9000'. Cmt bond OK. RU DA. Ran Howco DST tool on Dry Drill pipe & set tool @ 10025 opened tool to atmosphere & dry tested sqz perfs in Hemlock, POOH. Rigged up Dresser Atlas & perf'd Hemlock Bench #6 w/ 4 HPF f/ 10575' - 10622' using a 4" Junbo Jet csg gun. Made bit & scrpr run to the top of 7" liner @ 9785' - spotted 55 bbls clean W.O. fluid in well to re-perf "G" Zone. Perf'd "G" Zone using 4" Jumbo Jet 4 HPF as follows: G-5 9878' - 9892' 9824' - 9857' G-4 9702' - 9766' G-3 9660' - 9681' Dresser Atlas finished reperforating "G" Zone w/ 4 HPF using 4" jumbo jet G-2 9588' - 9610'. Ran 5 3/4" gauge ring on WL to 10450'. Ran 7" X 4" Otis "WD" perf pkr w/ 2 7/8" X N nipple on 9' tail on WL & set pkr @ 10400'. Ran Otis seal assembly on 3½" X 5" DP & stung, into pkr @ 1040[ Tested pkr to 400 psi - OK & POOH. Ran 7" X 4" Otis "WD" perm pkr on WL & set @ 10020'. Ran Otis seal assembly on 3½" X 5" DP & stung into pkr @ 10020'. Tested pkr to 400 psi OK & POOH. Change rams in BOPE & tested to UOCO specs. Rig up to run tbg. Finished rigging up dual equipment to run tbg. Ran Otis 4" X 12' seal assembly on 3½" LS & spaced out to 3½" X 2 7/8" X 9 5/8" Otis dual hydraulic pkr. Simultaneously ran 2 7/8" SS & 3½" LS after picking up dual pkr. Finished running dual 2 7/8" SS & 3½" LS tbg. Landed 310 jts (10005') 3½" 9.2# N-80 butt new tbg long string in 7" Otis perm pkr @ 10020' w/ end of tbg @ 10043', 12'. seal assy @ 10019', 220' of 3½" blast jts across G-2 thru G-5 perfs 9588' ~ 9892', 9 5/8" X 3½" X 2 7/8" Otis dual hyd pkr @ 9410', & 18 Camco GL mandrels w/ Macco GLV. Spaced out long .string & displaced tbg w/ FIW. Finished displaceing 3½" LS w/ FIW & stabbed into perm pkr @ 10020'. Tested pkr to 400 psi - OK. Displaced 9 5/8" X 3½" X 2. 7/8" annulus & 2 7/8" SS w/FIW. Ran WL plug & set in XN nipple @ 9425' in SS. Set 9 5/8" X 3½" X 2 7/8" Otis dual hyd p~r @ 9410' & tested SS to 3000 psi. Install BPV & ND BOPE. Install CIW dual 3½" 3000 psi X-mas tree & tested to 3000 psi. Placed well on GL & shut down rig @12:00 PM 12/22/77 for holiday. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT STATE WELL NO. TBUS G-30 FIELD TRADING BAY FIELD 2O DATE 1/05/79 ETD 11444' TD 10020' ETD (Perm Pkr) DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS Production tested on GL Hemlock Bench #6 perfs 10575' - 10585' (fill covering perfs 10585' - 10622' for 6 hrs @ less than 25 BPD gross rate cut 50%. Perforated Hemlock Bench #5 @ 10475' - 10535' with 4 HPF using 2 1/8" bi-wire torpedo jet under drawdown conditions. Production tested Hemlock Benches 5 & 6 perfs 10475' - 10585' for 6 hrs @ final rate of 168/50 BPD (70% cut). Released rig from G-30 @ 4:00 PM 1/05/78. Midnight stabilized test on G-30L was 185/80 BPD (54% Cut). G-30-S Test Prod. test after W.O. Gross Cut Net Oil 1094 2.5 1067 Prod. test prior to W.O. Gross Cut Net Oil 603 2 509 S EET D PAO !'b, FLEASE TRADING BAY UNIT STATE UNIO[i OIL CC ';o Ch' CALIFC IIA I,ELL ' i ,,F__L,U ~ ',,U 1'ELL [I0, G- 30 FIELD TRADING BAY FIELD ~,qTE FROM 10412.93 10412.12 10410.99 10410.04 10403.69 10043.84 10042.92 10041.40 10036.43 10023.69 10020. O0 10019.38 9988.11 9984.11 9892.22 9872.47 9860.37 9820.87 9773.90 9694.90 9690.45 9650.95 9619.45 9579.25 9456.60 9452.60 9421.10 9409.96 9398.76 9394~76 9333.76 9326.66 9016.45 9009.85 8669.71 8663.11 8322.58 8315.98 7944.57 7937.97 7626.92 7620.32 7277.93 7271.33 6929.21 6922.61 6612.59 6605.99 6265.18 6258.88 5915.84 5909.24 5599.30 5592.70 5250.37 5243.77 4903.34 TO 10412.12 10410.99 10410.04 10403.69 10400.00 10042.92 10041.40 10036.43 10023.69 10020.00 10019.38 9988.11 9984.11 9892.22 9872.47 9860.37 9820.87 9773.90 9694.90 9690.45 9650.95 9619.45 9579.95 9456.60 9452.60 9421.10 9409.96 9398.76 9394.76 9333.76 9326.66 9016.45 9009.85 8669.71 8663.11 8322.58 8315.98 7944.57 7937.97 7626.92 7620.32 7277.93 7271.33 6929.21 6922.61 6612.59 6605.99 6265.18 6258.58 5915.84 5909.24 5599.30 5592.70 5250.37 5243.77 4903.34 4896.74 DETAILS OF OPEP¢qTIONS, DESCRIPTIO~IS ~ RESULTS TUBI~G DETAIL - LONG STRING LENGTH *JTS DESCRIPTION .81 1.13 . .95 6.35 3.69 2 7/8" MULE SHOE Guide Otis 2 7/8" "XN" Nipple 2 7/8" 8RD x Butt X-Over Otis Seal Bore Ext. Otis 7" "WO" Perm. Pkr. .92 1.52 4.97 12.74 3.69 .62 31.27 4.00 91.89 19.75 12.10 39.50 46.97 3 1/2" Mule Shoe Guide Otis 3 '1/2" "XN" Nipple 3 1/2" Otis lORD Pup Tbg. 3 1/2" Otis Seal Assy Otis 7" Perm Pkr Otis Locator Sub 3 1/2" 9.2# N-80 Butt Tbg. Otis 3 1/2" "XA" Sleeve 3 1/2" 9.2# N-80 Butt Tbg. Otis 4 1/2" x 2.99" Blast Joint 3 1/2" 9.2# N-80 Butt Tbg. Otis 4 1/2" x 2.99" Blast Joint 3 1/2" 9.2# N-80 Butt Tbg. 79.00 4.45 39.50 31.50 39.50 123.35 4.00 31.50 11.14 11.20 4.00 61.50 6.60 301.21 6.60 340.00 ~6.60 340.53 6.60 371.41 6.60 311.05 6.60 .342.39 6.60 342.12 6.66 310.02 6.60 340.81 6.60 342.74 6.60 309.94 6.60 342.33 6.60 340.43 6.60 4 1 2 1 2 4 1 3 2 10 11 11 12 10 11 11 10 11 11 10 11 11 Otis 4 1/2" x 2.99" Blast Joints 3 1/2" 9.2# N-80 Butt Tbg. Otis 4 1/2" x 2.99" Blass ,Joints .3 1/2" 9.2# N-80 Butt. Tbg. Otis 4 1/2" x 2.99" Blast Joints 3 1/2" 9.2# N-80 Butt Tbg. Otis 3 1/2" "XA" Sleeve' 3 1/2" 9.2# N-80 Butt Tbg. Otis RDH 9 5/8" x 3 1/2" x'2 7/8" Dual Pkr 3 1/2" 9.2# N-80 Butt Tbg. Otis 3 1/2" "XA" Sleeve 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG" GLM #1 3 1/2" 9.2# N~80 Butt Tbg. Camco "KBUG" GLM #2 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG" GLM #3 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG' GLM #4 3 1/2" 9.2# N-80 Butt Tbg. Camco· "KBUG" GLM #5 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG" GLM #6 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG" GLM #7 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG" GLM # 8 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG" GLM #9 : 3 1/2" 9.2# N-80 Bu. tt Tbg. Camco "KBUG" GLM #10 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG" GLM #11 .. 3 1/2' 9,2# N-80 Butt Tbg. Camco "KBUG" GLM #12 3 1/2" 9,2# N-80 Butt Tbg. Camco "KBUG" GLM #13 3 1/2" 9.2# N-80 Butt Tbg. Camco "KBUG" GLM #14 S EET PAGE UNION OIL G CALIFCPCIIA I,ELL LEASE TB.&._[1TNG BAY UNIT qTATF . FIELD TRADING BAY FIELD DATE FROM ~896.74 4443.12 4436.52 3846.09 3839.q9 3001.65 2995.05 1994.86 1988.26 305.13 302.63 39.56 38.56 TO 4443.12 4436.52 3846.09 3839.49 3001.65 2995.05 1994.86 1988.26 305.13 302.63 39,56 38.56 - 0 - DETAILS OF OPEPATtONS, DESCRIPTIC. iIS & RESULTS TUBING DETAIL - LONG STRING CONTINUED LENGTH *JTS. DESCRIPTION 453.62 15 6.60 590.43 19 6.60 837.84 27 6.60 1000.19 32 6.60 1683.13 54 2.50 263.07 9 1.00 38.56 3 1/2" 9,2# N-80 Butt Tbg. Camco I'KBUG" GLM # 15 3 1/2" 9,2# N-80 Butt Tbg. Camco "KBUG" GLM #16 3 1/2" 9,2# N-80 Butt Tbg. Camco "KBUG" GLM #17 3 1/2" 9,2# N-80 Butt Tbg. Camco "KBUG" GLM #18 3 1/2" 9,2# N-80 Butt Tbg. Otis 3 1/2" "XL" Nipple (Ball Valve) 3 1/2" 9.2# N-80 Butt Tbg. CAMERON DUAL 3 1/2" HANGER LANDED BELOW ZERO D PAGE " UHIO!I OIL CQ'- ?Ah'Y CALIFCP, IIA I,'ELL i'PT'p,pT1 LEASE TRADING BAY UNIT STATE t iO, TBUS G-30 FIELD TRADING BAY FIELD DATE FROM 9427.49 9425.99 9419.79 9400.96 9408.28 9376.92 9373.19 9309.66 9303.06 8985.73 8979.13 8722.78 8716.18 8348.56 8341.96 8004.25 7997.65 7652.59 7645.99 7343.23 7336.63 6965.42 6958.82 6487.08 6480.48 5947.7'1 5941.11 5285.80 5279.20 4320.58 4313.98 3191.35 3184.75 2088.92 2082.32 333.36 332.56 302.91 300.41 39.53 38.53 TO 9425.99 9419.79 9409.96 9408.28 9376.92 9373.19 9309.66 9303.06 8985.73 8979.13 8722.78 8716.18 8348.56 8341.96 8004.25 7997.65 7652.59 7645.99 7343.23 7336.63 6965.42 6958.82 6487.08 6~80.48 5947.71 5941.11 5285.80 5279.20 4320.58 4313.98 3191.35 3184.75 2088.92 2082.32 333.36 332.56 302.91 300.41 39.53 38.53 = 0 - DETAILS OF OPEP~TIONS, DESCRIPTIOilS & RESULTS , , TUBING DETAIL - SHORT STRING LENGTH *JTS DESCRIPTION 1.50 6.20 1 9.83 1.68 31.36 1 3.73 63.53 3 6.60 317.33 13 6.60 256.35 11 6.60 367.62 14 6.60 337.71 13 6.60 345.06 14 6.60 302.76 11 6.60 371.21 16 6.60 471.74 20 6°60 532.77 · 21 6.60 655.31 25 6.60 958.62 37 6.60 1122.63 33 6.60 1095.83 45 6;60 1748.96 65 .80 29.65 1 2.56 260.88 9 1.00 38,53 OTIS 2 7/8" "XN" NIPPLE 2 7/8" 6.4# N-80 Butt. Tbg. OTIS "RDH" 9 5/8" x 3 1/2" x 2 7/8" DUAL PK,~ 2 7/8" 8RD x 2 7/8" Butt X-Over 2 7/8" 6.4# N-80 Butt Tbg. OTIS 2 7/8" "XA" SLEEVE 2 7/8" ~6.4# N-80 Butt Tbg. Camco "KBMG" GLM #1 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #2 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #3 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #4 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #5 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #6 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #7 2 7/8" 6.4# N-.80 Butt Tbg. Camco "KBMG" GLM #8 2 7/8" 6.4# N-80 Butt Tbg.' Camco "KBMG" GLM #9 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #10 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #1.1 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #12 2 7/8" 6.4# N-80 Butt Tbg. Camco "KBMG" GLM #13 2 7/8" 6.4# N-.80 Butt Tbg. Camco ".KBMG" GLM #14 2 7/8" 6.4# N-80 Butt Tbg. 2 7/8" Butt x 3 1/2" Butt X-Over 3 1/2" 9.2# N-80 Butt Tbg. OTIS "XL" NIPPLE (BALL' VALVE) 3 1/2" 9.2# N-80 Butt Tbg. CAMERON DUAL 3 1/2" HANGER LANDED BELOW ZERO -* (NOTE: Number of Joints inCluding pup joints) __ TRUS G -_.30 3 1/2" OTIS SAFETY VALVE @ 300' 3 1/2" TO 2 7/8" X-OVER 0333' 17 3/4" C 5201' 13 3/8" C. 4779' 7/8" 01IS "X^" SkEEVE @ 9393' 8" /2" 0TIS 9 5/ x 3 I x 2 7/8" RDH @ 9419' 2 7/8" "XN" @ 9426' TOP 7" @ 9785' 9 5/~" C. 9866' 3 1/2" OTIS SAFETY VALVE @ 303' _-. 3 1/2" OTIS "XA" SLEEVE @ 9395' OTIS 9 5/8" x 3 1/2" x 2 7/8" RDH @ 9410' 3 1/2" OTIS "XA" SLEEVE @ 9453' 3 1/2" OTIS "XA" SLEEVE @ 9844' OTIS 7" x-4" "WD"PACKER 10024' 3 1/2" OTIS "XN" Nipple @ 10036' 3 1/2" Mule Shoe @ 10043' OTIS 7"--X 3 1/4" "WD" PACKER @ 10400' 2 7/8" OTIS "X'N" Nipple @ 10411' · 2 7/8" Mule Shoe @ 10412' G - 30 TRADING BAY UNIT STATE McARTHUR RIVER FIELD ' Started 12-4-77 Completed 1-5-78 U;.'[L.',,,' t..,,L C:$,,:;-'AN'( OF C,',LI; C;..,-:lr, t Fo;.'n 10-40~ REV. 1-10.7~ ' ' Subml t "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.) ~' O,L ~ GAs WELLL~J WELL OTHER 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR P.O. Box 6247, Anchorage, Alaska 99502 4. LOCATION OF WELL At ~dace Cond. #44, 1876'N & 1378'W from the S.E. 29, T9N, R13W, S.M. corner, Sec. 13. ELEVATIONS (Show whether DF, RT, GR, et~) 99' RT Above MsL 14. Check Appropriate Box To Indicate Nature of Notice, Re ..... [ ico,~M'KI · 50-133-20107 F-~-~ ~! ~ , z ;:17,,~ 6. L~SE D~IGNATION ANDSER~~ ~:-~ ~'- 7. IF INDIAN, ~LLO~EE OR TRIB~[ N~N ~ " ,. UN~T, FARM OR g~SE NAME ~ j STAT 10. FIELD AND mOL, OR WlLDC~LF: '" -~ HcA~hu~ [lve;T~eid 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 33: T9N, R13W, S.M. 12. PERMIT NO. 59-47 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEs Report results of multiple completion on Well COmpletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS: (Clearly state all I~ertlnent detillls, and give pertinent dates, including estimated date. of starting any proposed work. The Upper Hemlock Benches in G-30L, Grayling Platform, McArthur River Field, Cook Inlet, Alaska, were perforated as follows: * le Pulled ball valve. Rigged up Dresser Atlas and test lubricator to 2000 psig. Perforated the following intervals at 4 hpf using 2~t/8" slimkone guns.: B - 1 10,058 - 88 B - 3 10,230 - 80 B - 4 10,300 -90 4. Ran ball valve and returned to production. *Verbal approval received from Russ Douglass, 12/10/79. 16. I hereby certify that the foregoing is true and correct Dist. Drlg. Supt. DATE 12/17/79 (This space for State office use) APPROVED BY, CONDITIONS OF APPROVAL, IF ANY.. TITLE See Instructions On Reverse Side DATE Union Oil and Gas [~'~ ,ion: Western Region Union Oil Company of California P.O. BOX 6247, Anchorage, Alaska 99502 Telephone: (907)276-7600 January 29, 1978 ~r. O. K. ~ilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE' TBUS G-30 Grayling Platform Dear Mr. Gilbreth' Enclosed for your information are two copies each of the Subsequent Sundry Notice for the abandonment and recompletion in a new zone .for the above captioned project. Si ncerely yours, ~Callender Dist. Drlg. Supt. sm Encl. RECEIVED FE 0 - 't 1978 D:vision of Oii and t%s Canse~ation Anc.,horage Form '10-403 REV. 1-10~73 Submit "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.) O,L ~ GAS F-I WELL I..~J WELL L.-J OTHER 2. NAME OF OPERATOR Union Oil Company of California 5, APl NUMERICAL CODE 50-133-20187 6. LEASE DESIGNATION AND SERIAL NO. ADL-18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit ~. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 6247, Anchorage, AK 99502 TBUS G-30 (11-33) 4. LOCATION OF WELL At surface Conductor #44: 1876'N & 1378'W from the SE corner, Section 29' T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT McArthur Ri ver Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 33' T9N, R13W, S.M. 12. PERMIT NO. 69-47 =ort, 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) (NOTEI Report results of multiple completion on Well ComPletion or Recompietion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent details, and give pertinent dates, including estimated date of starting any proposed work. The West Foreland Zone of'this well is abandoned. It was necessarY to shut off this Zone due to low oil production with a high water cut' The perforations were from 10,719'-11,299'. Prior to abandonment, production was 540/108 B/D at 80% cut. These perfs were squeezed through a 7" retainer placed at 10,695' with 150 sx. of cement. A 25' cement plug was placed on the retainer with the top of the plug at 10,670'. The cased hole below the abandoned Zone was previously displaced with filtered inlet water. 16. I hereby certify that the foregoing is true and correct //,~im.. R_ Call.hillY, T ....~ ..... T (This space for State office use) APlIROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE Dist. Drl~. Supt. ,, DATE ,, 1/17/78 DATE See Instructions On Reverse Side Forrr~ 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.) ~' o,L I~1 GAs [--! WELLv~ I WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California 5. APl NUMERICAL CODE 50-133-20187 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 6247, Anchorage, AK 99502 Tgi. IS a-30 (11-33) 4. LOCATION OF WELL At surface Conductor #44: 1876'N & 1378'W from the SE corner, Section. 29' T9N, R13W, S.B. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' *RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND 1~3OL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 33- T9N, R13W, S.M. 12. PERMIT NO. 69-47 )ort, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING ~ WATERSHUT-OFF ~;esu~;;f ---. -.--.---v..-- REPAIRING WELL ~Well FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIRWELL CHANGEPI-ANS (Other)_ [~_C_n.m..n_~.¢~-,~ ';n nat,; -~nnc~ , (Other) (NOTE, Re.om multiPlecompletion on ComDletlon or Recompletion Report and Log form.) ~'~. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent (let&Us, and give pertinent dates, Including estimated date of starting any proposed work. The long string of this well has been completed as a Hemlock producer. The formerly completed West Foreland Zone was plugged and abandoned and Benches 5 and 6 of the Hemlock formation were perforated as follows- Bench 5 Bench 6 10,475'-10,535' 10,575'-10,622' Benches 5 and 6 were acidized with 5000 gal. HC1 followed by 4500 gal. of diesel. The long string is 3 1/2" tubing with a dual packer set at 9410' and a single packer set at 10,020'. A packer assembly is set at 10,400' with wireline capability of isolating Benches 5 and 6 from the rest of the Hemlock formation. The 2 7/8" shOrt string is completed as a "G" Zone producer. This Zone is the same C as the previous "G" Zone completion with intervals repeforated as follows- · G-2 9588'-9610' G-3 9660'-9681 ' . G-4 9702'-9766' G-5 9824'-9857' 9878'-9892' 16. I hereby certify that the foregoing is true and correct ~' dim ~. Cai lender/ (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE Dist.~Drl9. Supt. DATE , 1/17/78 DATE See Instructions On Reverse Side Union Oil and Gas L~*~ , on' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska"'g'9-5'~ Telephone: (907) 276-7600 union January 13, 1978 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE: TBUS G-30 GRAYLING PLATFORM Dear Mr. Gilbreth' Enclosed for your files are three (3) copies of the monthly report for the above captioned project. Sincerely yours, ~J~t~. Callender Dist. Drlg. Supt. sm cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Chevron USA Getty Oil Co. Phillips Petroleum Co. USGS Harry Lee ~:atm No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS $. AP! NUMERICAL CODE 50-133-20187 6. LEASE DESIGNATION AND SERIAL NO. ADL 18730 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL GAS WELL OTHER _~NIT F. ARM OR...LEASF~AM~ 2. NAME OF OPERATOR 8. I radlng ~ay unll: Union Oil Company of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 Conductor #44' 1876'N & 1378'W from the ~,i,~ ~-~ ~-~ ~'~-'~,~ i~L ' SE corner, Section 29' T9N, R13W, S.M. j).."i ~. '~ ':' "~c' 9. WELL NO. TBUS G-30 (11-33) 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 33: T9N, R13W, S.M. ' 12Z) ~ERMIT NO. 69-47 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 12/4/77 11,444 'TD 10,621 'ETD (perm pkr) 13 3/8" csg. @4779' 9 5/8" csg @9866' 7" 1 iner Before activation of Rig #54 an attempt was made to pull GLV from G-30 L.S. w/ slick line unit and was unable to work tools below obstruction @3318'.. Returned well to production. After completion of activation RU Dresser Atlas and ran perf gun in L.S. and could not get below 3318'. Filled 9 5/8" x 3 1/2" annulus w/ 66#/cu.ft. W.O. fluid. Annulus and both tbg. strings dead. Installed BPV & removed X-mas tree. NU 12" 3000 psi BOPE & riser. Tested to UOCO specs. RU to @9785'-11,444' pull dual 3 1/2" tbg. strings and could not release Otis hyd. pkr. @9409'. While working tbg. to 165,000# parted dual elevator bail. RD Weatherford & RU Camco. 12/5/77 11,444 'TD 10,621 'ETD (perm pkr) 13 3/8" cs§ @4779' 9 5/8" csg @9866' 7" liner @ 9785 '-I 1,444 Completed pulling 9 GLV from 3 1/2" short string tbg. and clos all sleeves in GL mandrels. Tested tbg. o.k. and opened CX sleeve at 9377' above Otis dual hyd. pkr at 9406' Circ. out produced fluids in short string and conditioned W~ fluid. RD Camco slickline unit. RU Dresser Atlas. 12/6/77 11,444 'TD 10,621 'ETD (perm pkr) 9 5/8" csg @9866' 13 3/8" csg Finished running Dresser Atlas free point indicator on 3 1/2" short string indicating tbg. free to dual hyd pkr @9409'. Pulled 150,000# to move tbg. @9409' for free point. Ran DA 2 9 /16" od tbg cutter and cut 3 1/2" short string @9406'. Pulled and laid down 303 jts plus 1 piece 3 1/2" tbg. (98,000# to move tbg. off bottom). Pulled 160,000# on 3 1/2" long 14. I hereby certiLv teat tltc~rore~ng~ue ami corr0~t .... SIGNED (~1~. ~1~ ~}f~,~//~TITLE Dist,Drlg. Supt. 1/13/78 , f/.q'~ ~. [~ r[end~ -! DATE , NOTE-Re~o~ on this form is requ~d for each calendar month, regardle, of the ~atus ~f operatiom, and mu~ be filed in duplicate with the oil and gas conservation committ~ by the 15th of tho succ~ing month,unl~ otherwise dir~t~. 12/7/77 @4779' string and released hyd. pkr @9409' Pulled seal assy. free fror 7" liner @ perm. pkr. @10,621' and circ. bottoms up. Spotted 50 bbl of 9785'-11,444' FI.W w/ 25#/bbl Dril-S and 21'~/bbl safe seal across "G" zone perfs 9588' -9977'. Pulled and LD 3 1/2" long string, incomplete. ll,444'TD Completed pulling and LD 341 jts of 3 1/2" L.S. tbg. Changed lO,621'ETD rams in BOPE & tested to UOCO specs. Ran 5 7/8" od burnover (perm pkr) shoe on 7' jt of 5 3/4" washpipe on two 4 3/4" od drill 13 3/8" csg collars and 1700' of 3 1/2" DP. TIH picking up 5" od DP. @4779' While PU DP @4800' - broke high drum chain in drawworks 9 5/8" csg (Note- bearing failed on low drum and allowed low positive @9866' clutch to engage main drum shaft while running in high drum 7" liner @ & caused high drum chain to break). Tore down drawworks & 9785'-11,444' rolled drum out of drawworks for repairs. Parts ordered from National Supply in Torrence, California. Due to arrive at 8'30 a.m. 12/8/77 11,444 'TD 10,621 'ETD (perm pkr) 9 5/8" csg @9866' 13 3/8" csg @4779' 7" liner @ 9785'-11,444' Repair parts for drawworks scheduled to arrive from California at 8:30 a.m. 12/8/77 were lost in transit After tracing and rerouting, parts arrived in Anchorage at Replaced both brake flanges and brake pads drawworks while waiting on repair parts. 12/9/77 11,444 'TD 10,621 'ETD (perm pkr) 9 5/8" csg @9866' Waited on bearing to repair National 1320 drawworks to be flown from Anchorage to platform after arriving in Anchorage from California at 11:20 p.m. 12/8/77. Installed replacement bearing on shaft and inner race on bearing cracked due to factory defect. Ordered new bearing from California arriving Anchorage 7" liner at 3'30 p,m. 12/8/77. Installed bearing and re-assembled 9785'-11,444' drawworks. 12/10/77 ll ,444'TD 10,621 'ETD (perm pkr) 9 5/8" csg. @9866' 7" liner @ 9785'-11,444' Repairs complete at 2:00 p.m. 12/9/77 (total down time 75 1/2 hrs). Continued running 5 7/8" burnover shoe, 7' of 5 3/4" washpipe and two 4 3/4" DC on 1729'- 3 1/2" DP. Finished PU 5" DP rubbering every other jt. and RIH to Baker Model F perm pkr @10,621' (10,630' DPM). Burned over pkr for 1 1/2 hrs. 12/11/77 ll,444'TD ll ,182'ETD (perm pkr) 9 5/8" csg @9866' Cont. burning over pkr for 12 hrs-and pipe torqued two times when pkr started moving down hole. PU and checked weight then chased pkr down to 1t,182' and pkr hung up. Circulated bottoms up and pooh w/ DP. Rec lO1 jts 5" DP and 17 jts 3 1/2" DP w/ pin threads on last jt. of 3 1/2" DP pulled and 7" liner @ jumped from box. Left in hole 5 7/8" od burnover shoe, 7' 9785'-11,444' of 5 3/4" washpipe, 4 3/4" boot basket 2 4 3/4" DC, and 39 jts (1204') 3 1/2" 13.30# Grade E DP. Total fish 1279.86' w/ top of fish @9902' (117' inside 7" liner). 12/12/77 11,444'TD ll ,182'ETD (perm pkr) 9 5/8" csg @9866' Finished PU 5 3/4" overshot w/ extension dressed w/ 4 3/4" mi' control and 4 3/4" grapple, bumper sub and jars on 3 1/2" x 5" DP. RIH to top of fish (3 1/2" DP box) @9902'. Dressed and engaged fish in 1/2 hr. Pooh and rec.all of fish. No damage to tools except jumped box on top jt. of 3 1/2" DP. 7" liner@ LD burnover & fishing tools. Ran 6" bit, 7" csg scraper & th~ 9785'-11,444' 4 3/4" DC on 3 1/2" x 5" DP to perm pkr left @11,182' and circ. bottoms up. Pooh Temp switch charges from AFE #37144~ to AFE 371444 @12'00 midnite 12/12/77. 12/13/77 ll,444'TD ll ,182'ETD (perm pkr) 9 5/8" csg csg[a9866' Commenced operations on AFE #371444 at 12'O1 a.m. 12/13/77. RU Dresser Atlas logging unit & ran Compensated Nuetron-Gamma Ray Log over zone of interest 10,700'-9500'. Ran Log #2 Nuetron-Lifetime Log 10,700'-9500'. Ran Log #3 Carbon Oxygen Log. 12/i14/77 '11,'444'TD. 11,182'ETD .(junk pkr) 9 5/8" csg @ 9866' 7" liner @ 9785'-11,444' F~m}s-h.ed running DA C/O log #3 from"lO,700' t'o 9500~. 'RD-- logging unit. Charges ceased on AFE #371444 at 6'00 a m. 12/14/77 · 12/14/77 ll ,444'TD lO,695'ETD (junk pkr) 9 5/8" csg @9866' Recommenced charges on AFE #371443 at 6'00 a.m. 12/14/77. Ran 7" Howco cmt ret on W.L. and .set at 10,695'. RD W.L. uni~ Ran ret stinger on 3 1/2" x 5" DP and stung into ret @10,695'. Broke down West Foreland perfs 10,712' to 11,299' at 2500 psi and pumped in at 12 cu.ft./min & 2500 psi. Held 1375 psi aftE 7" liner @ l0 min w/ pump off. Squeezed for aband6nment west Foreland. 9785'-11,444' perfs 10,712' to 11,299' w/ 150 sx. C1 "G" w/ .75% D-31, .3% D-13, .1% D-6 mixed at ll6#/cu.ft, to a final pressure of 2600 psi at 8 cu.ft./min. Held 2100 psi after 10 min w/ pump off. Pulled out of ret and dumped 10 cu.ft, cmt. plug from 10,695' to 10,647' Pooh w/ DP. Charges ceased on AFE #371443 at 12'~0 midnite 12/14/77 12/15/77 11,444'TD lO,192'ETD (cmt ret) 9 5/8" csg 9866' Restarted charges on AFE #371 @12'01 a.m. 12/15/77. RU DA and perf 4 holes @10,418'-10,420' for WSO sqeeze. Ran 7" Howco cmt. ret on W.L. & set @10,395'. Ran stinger on 3 1/2" x 5" DP and set in ret @10,395'. Broke down sqz. hole 10,418' to 10,420' @3450 psi and PI at 4 1/2 cu.ft./min & 3450 psi. 7" liner Mixed and pumped 100 sx CL "G" w/ .75% D-31, .3% D-13 and @9785'-11,444' .1% D-6 mixed at ll8#/cu.ft. Squeezed perfs 10,418' to 10,420' for WSO to lockup @5000 psi w/ 90 cu.ft, slurry. Held 5000 psi for 5 min. Bled pressure to 2500 spi. Pulled out of ret & dumped 25 cu. ft. cmt on ret. Pooh and RU DA. Perf 4 holes at 10,215' to 10,217' for WSO squeeze. Ran 7" Howco cmt ret on W.L. & set @10,192'. Ran stinger on 3 1/2" x 5" DP and set inret @10,192'. Broke down sqz. hole 10,215'-10,217' @4800 psi and PI @ 4 cu.ft./min & 3600 psi. Mixed and pumped 75 sx CL "G" w/ .75% D-31, .3% D-8 & .1% D-6 mixed @ll8#/cu.ft. Squeezed perfs 10,215'-10,217' for WSO to lockup @5000 psi w/ 68 cu.ft, slurry. Held 5000 psi for l0 min. Bled to 2500 psi. Pulled out of ret & dumped 20 cu. ft. cmt on ret. Pooh. Ran 6" bit, two 5 7/8" boot baskets, and three 4'3/4" DC on 3 1/2" x 5" DP to TOC @10,106'. 12/16/77 ll,444"TD 10,670' ETD (cmt plug) 9 5/8" csg @ 9866' Cont drilling out WSO squeeze cmt inside 7" liner from 10,150' cmt ret @ 10,192'. Drilled ret and hard cmt across WSO perfs 10,215'-217' and fell free to 10,245'. Drilled cmt from 10,245' to cmt ret @ 10,395' and made bit trip. Drilled ret @10,395' and found no cmt across WSO perfs 10,418'-420' Ret pushed · 7" liner @ free to 10,439' Drilled hard cmt from 10,439' - 10,522' and 9785'-11,444' fell free to 105610'. Drilled hard cmt from 10,610' to 10,670' (leaves 25' cmt plug on West Foreland abandonment ret @10,695'). Circ hole clean and spotted 110 bbl of fresh FIW w/ lO#/bbl Dril and 18#/bbl KCL from 10,670' -8730'. Pooh. 12/17/77 ll ,444'TD lO,670'ETD (cmt plug) 9 5/8" csg @ 9866' Ran 6" bit and 7" csg scraper on 3 1/2" X 5" DP to 10,670'. Circ bottoms up and spotted 110 bbl fresh FIW w/ 18#/bbl Dril-S 18#/bbl Safe-Seal, and 18#/bbl KCL from 10,670'-8730' for perforating Pooh. Rigged up Dresser Atlas and ran Gamma-Ray C.B.L. signature log from 10,670' to 9000'. Cement bond - 7" liner @ O.K.R.D. Dresser Atlas. Ran Howco D.S.T. tool on Dry Drill 9785'-11,444' pipe & set tool @10,025 opened tool to atmosphere & dry tested sqz. perfs in Hemlock - O.K. 12/18/77 11,444'TD 10,670' ETD (cmt plug) 9 5/8" csg @ 9866' 7" 1 iner @ 9785'-11,444' Rigged up Dresser Atlas & perforated Hemlock Bend #6 with 4 HPF from 10,575 - 10,622 using a 4" Jumbo Jet casing gun. Made a bit & scraper run to the top of 7" liner ~@9785 - spotted 55 BBLS clean W.O. fluid in well to re-perf "G" Zone. Perforated "G" Zone using 4" Jumbo Jet 4 HPF as follows: G-5 9878-9892 9824-9857 G-4 9702-9766 G-3 9660-9681 12/19/77 11,444'TD lO,670'ETD (cmt plug) 9 5/8" @9866' 7" liner @ 9785'-11,444' Dresser Atlas charges to reperforate the "G" Zone according to procedure @ selected intervals from 9588'-9892' on 12/18/77 charged to AFE # 371443. 12/19/77 ll,444'TD Dresser Atlas finished reperforating "G" Zone w/ 4HPF using 4" IO,020'ETD jumbo jet @ G-2 9588"-9610'~'WD'Ran4'' 5 3/4" gage ring on WL to 9 5/8" csg @ 10,450'. Ran 7" x Otis perf pkr with 2 7/8" x N 9866' nipple on 9' tail on WL and set pkr @ 10,400'. Ran Otis seal 7" liner @ assembly on 3 1/2" x 5" DP and stung into pkr @10,400'. Tested 9785'-11,444' pkr to 400 psi -O.K. & pooh. Ran 7" x 4" Otis "WD" perm pkr o WL and set @ 10,020'. Ran Otis seal assembly on 3 1/2" x 5" DP and stung into pkr @ 10,020'. Tested pkr to 400 psi - O.K. &' pooh. Change rams in BOPE & tested to UOCO specs. Rig up to run tbg. 12/20/77 11,444'TD 1 O, 020' ETD (perm pkr) 9 5/8"@ 9866' 7" liner @ 9785 '-11,444 Finished rigging up dual equipment to run tbg. Ran Otis 4" x. 12' seal assembly on 3 1/2"'LS and spaced out to 3 1/2" x 2 7/8 9 5/8" Otis dual hydraulic pkr. Simultaneously ran 2 7/8" SS a 3 1/2" LS after picking up dUal pkr. Short string requiring extensive uSe of pup its due to average jt length difference between 2 7/8" SS (28-29') and 3 1/2" LS (31-32'). 12/21/77 ll,444'TD IO,020'ETD (perm pkr) 9 518"@ 9866' 7" 1 iner @ Finished running simultaneously 2 7/8" SS and 3 1/2" LS tbg. Landed 310 jts (10,005') 3 1/2" 9.2# N-80 butt new tbg long string in 7" Otis perm pkr @ 10,020' with end of tbg @ 10,043', 12' seal assembly @ 10,019', 220' of 3 1/2" blast jts across G-2 thru G-5 perfs 9588-9892', 9 5/8" x 3 1/2" x 2 7/8" Otis dUal hyd pkr @ 9410', and 18 Camco GL mandrels with Macco GLV. 9785'-11,444' Spaced out long string and displaced tbg w/ FIW. 12/21/77 11,444'TD 10,020 'ETD (perm pkr) 9 5/8" @ 9866' 7" liner @ 9785-11,444' Finished running 2 7/8" SS simultaneously w/ 3 1/2" LS. Landed 288 its + 67 pup jts (9389') 2 7/8" 6.4# N-80 butt used tbg sho~ string with end of tbg @ 9427' 9 5/8" x 3 1/2" x 2 7/8" Otis dual hyd pkr @9410', and 14 Camco GL mandrels with Macco GLV. Spaced out short string and closed valve while valve displacing 12/22/77 ll,444'TD IO,020'ETD (perm pkr) 9 5/8"@ 9866' 7" liner @ Finished displacing 3 1/2" LS w/ FIW and stabbed into perm pkr @ 10,020'. Tested pkr to 400 psi - O.K. Displaced 9 5/8" x 3 1/2" x 2 7/8" annulus & 2 7/8" SS w/ FIW. Ran WL plug and se1 in XN nipple @ 9425' in SS. Set 9 5/8" x 3 1/2" x 2 7/8" Otis dual hyd pkr @ 9410' & tested SS to 3000 psi. Install BPV and ND BOPE. Install CIW dual 3 1/2" 3000 psi X-mas tree & tested 9785'-11,'444' to 3000 psi. Placed well on GL & shut down rig @ 12:00 P.M. 12/22/77 for holidays. Will remain shut down untill 1/4/78 to allow wireline work to be completed. Form 10-40.3 REV. 1-"10-73 $~b~lt "1 ntentlons" in Triplicate & '*Subsequent Reports" in Duplicate STATE OF ALASKA OiL ,.'~d~D GAS CONSERVATION COMM ITTE E 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 Co..of Calif. 3. ADDRESS, OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 LOCATION OF WELL At su trace Conductor #44' 1876'N & 1378'W from the. SE corner - Section 29- T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20187 6. L~SE DESIGNATION AND SERIAL NO. ADL-18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq Bay Unit 9. WELL NO. State G-30 (11-33) 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 33' T9N, R13W, S.M. 12. PERMIT NO. 69-47 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* . (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (clearly state all pertinent details, and give pertinent dates, including estimatect date of starting any proposed work. The well was completed as a dual "G" zone - West Foreland oil producer in July, 1969. The West Foreland is'presently producing 540/180 B/D at 80% cut with cumulative production of 1.1 million bbls of oil. The present producing rate is very close to the economic limit and past workover or stimulation attempts have been unsuccessful. It is proposed to abandon the West Foreland and recomptete the well as a dual "G" zone - Hemlock oil producer. A 7" cmt. ret. will be set at 10,700' above West Foreland producing perfs 10,712'-11,299'. The perfs will then be squeezed with a minimum of 125 sx. and a 30' cmt. plug will be dumped on the retainer. A more complete procedure and wellbore schematic are attached. RECEIVED NOV g O 1977 16. I hereby certify' that the foregoing is true and correct ,:/~./dim R_ C_.a!!ender , (This s~a'~e for State office use) APPROVED BY /~ ~-c~-"~~ TITLE CONDITIONS OF APPR. OVAL, iF ANY:// Dis~;, Drlg. supt.. DATE, 1!/28/77 Petroleum Engineer See Instructions On Reverse Side DATE 12-02-77 .Approved Copy Ret~med I. Following completi(- of turnaround and activation of Rig #54 over ~o leg #2, rig up over TBUS G-30. 2. Kill well with wor~:over fluid. 3. Install and test BOPE. 4. Pull dual 3 1/2" tubing strings. 5. Cut over pkr. at 10,621' and push to +il,350' 6. Run Dresser Atlas C/O (carbon oxygen) log from 10,700' to 9500'. 7. Set 7" cmt. ret. at 10,700'. 8. Squeeze for abandonment West Foreland perfs 10,712'-11,299'. 9. Reverse hole clean and pooh. 10. Reperforate G-2 through G-5 sands before running production tbg. EX ] ST ;r~.'~G PERFORAT IO~S- "G" Zone G-I 9537'-9563' (squeezed) G-2 9588'-9610' G-3 9660'-,968]' G-4 9702'-9766' G-5 9824'-9857' G-5 9878'-9892' G-6 9956'-9977' West Foreland 10,712'-10,728 10,828'-10,838 10,860'-10,875 10,883 -10,891 10,895 -10,899 10,902 -10,914 11,078 -11,130 11,179 -11,216 11,264 -11,299 G -30 NTb Z Pr, ed L 9409' Ofi~ ~1 hv4 9400' 0+;~ dual hyd 9588'- 9BgZ' ~-Z +hru ~-$ r~n toooo' gekor Nodal F-I t~ RECEI.V NOV 38 A~h~t~ /04,30' 10621' l~er t'~odM F j~rm pgr t06~0'-652' tx~a ~e;rl w,14~,~ (2jv&) 10670' cm* joia 10700' cm~- ?~ Form 10-403 REV. 1-10-73 Subml t *'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.) 5. APl NUMERICAL CODE 50-133-20187 6. LEASE DESIGNATION AND SERIAL NO. APL - 18730 7. IF ,ND,AN. ALLOTTEE OR TR,BE NAME ~' O,L k--fl GAS r-1 WEL. L~"'~ WELL L.--I OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Union 0il Co. of Calif. Trading. Bay Unit 0. Box 6247, Anchorage, AK 99502 State G-30 (11-33) 4. LOCATION OF WELL At surface Conductor #44' 1876'N & 1378'W from the SE corner- .Section 29- T9N, R13W, S.M. 13. ELEVATIONS (Show w~ether DF, AT, GA, etc.) 99' above MSL Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section. 33' T9N, R13W, S.M. 12. PERMIT NO. 69-47 )orr, or C)ther Data NOTI~CE OF INTENTION TO: FRACTURE TRE~T MULTIPLE COMPLETE SHOOI OR ACIIDIZE ABAN DON * REPAIR WELL CHANGE PLANS (Othe~j Pecomp!ete in .n.e':! 7nqP, , SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DE. ExCRI~BE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of The well is presently completed as a dual "G" zone - West Foreland oil producer. Since the West Foreland production has dropped very close to the economic limit and workover attempts have proven unsuccessful, it is proposed to recomplete the well as a dual "G" zone - Hemlock oil producer. The West Foreland zone 10,712'-11,299' will be squeezed below a cmt. ret. at 10,700'. A carbon-oxygen log will be run and Hemlock Benches 5 and 6 will be perforated for production. Dual tbg. string will then be run and the well placed on production. A more detailed procedure and wellbore schematic are attached. RECEIVED NOV g LB 1977 Division of 0!I & ~':~ Conservation Anchorage 16. I hereby cert, J~l( that the foregoing Is true and correct //dlm R. Cal lp_nd~r T,TLE Dist. Drql, SNOt. · DATE l_ !/28/77 (This space for State* office use) CONDITIONS OF APPROVAL, IF ANY:.// Petroleum Engi neet See Instructions On Reverse Side 12-02-77 DATE Approved "'a.~ ,, Retume~ Sundry Notices & Reports on Wells TBUS G-30 11/28/77 Page 2 PLAN OF PROCEDURE: 1. Perf and squeeze for zone isolation at 10,420' and 10,215'. 2. Clean out cmt. and dry test squeezes. 3. Perf and DST Hemlock Bench 6 as required after interpretation of C/O log. 4. Perf Hemlock Bench 5 at 10,435'-10,525'. 5. Reperforate G-2 through G-5 sands as follows: G-2 9588'-9610' G-3 9660'-9681' G-4 9702'-9766' G-5 9824'-9857' 9878'-9892'. 6. Run dual 2 7/8" and 3 1/2" production equipment. 7. Place well on gas lift production as dual "G" zone-hemlock Bench 5 and 6 producer, with mechanical provisions to perforate Hemlock Benches 1 - 4 thru tbg. RECEIVED NOV 819Tf Division of 0!t & ~.§ ConservatiOn f T8~'5 bU ci l~o~ G -30 IriT~ Z Z RECE[ Division of O~t & k 9, Z ~ A/-SO 94~'0-1-;o ~ai hr4 ?~r /oooo' Bak~ MM./ F-I t~n~ t~kr ~rvat]on i0621' 8aRer ~odM F ~-m 10670' em 10700" omc plus Hoyle Hamilton State of Alaska Division of Oil & Gas 3001 Porcupin~ Dr. Anchorage, Alaska 99502 Union Oil and Gas ~'~' 'sion' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 9950~- · e,e. one: union November 1, 1976 Dear Sir: Enclosed are Sundry Notices for we,ils G-30 and G-12RD for your information. ~ .................. " Yours very truly, G. A. Graham Union Oil Company of California 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 tills form for proposals to drill or to cleel3en Use "APPLICATION FOR PERMIT---" for such ProPosals.) :5. APl NUMERICAL CODE 50-133~-20187 6. LEASE DESIGNATION AND SERIAL NO. AD~,-18730 7. ,F ,ND,AN. ALLO', ,'EE OR TH,BE NAME 1. O,L ~ GAS r-'] WE LL i..Y~..I WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Union Oil Company of California Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 909 W. 9th Avenue, Anchorage, Alaska 99501 State G-30 (11-33) 10. FIELD AND POOL, OR WILDCAT McArthur River Field 4. LOCATION OF WELL Atmdace Conductor #44: 1876'N and 1378"W from the SE ~orner. Section 29: T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, et~) 99'RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 33: TgN, R13W, S.M. 12. PERMIT NO. 69-47 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* 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 estimatecl date of starting any proposed work. Began operations October 15, 1976 1. Pulled ball valve 2. Pulled all gas lift valves 3. Perforated the following West Foreland intervals: 10712-10727 15' 10828-10838 10' 10860-10875 15' 10882-10913 30' 1~080-11130 50' 11180-11195 15' 135' TOTAL (Fill at 11196') 4. Reran all gas lift valves 5. Acidized in six (6) stages by pum~in§ dow~ the tubin~ with a maximum pressure of 2000 psi. Total Volume Pumped: 11,400 gal 50/50 P-20 SOlvent and 7 1/2% HC1 with addit±~es. 22,800 gal 25/75 P-20 Solvent and 12-10 HCl-HF with additives. 11,550 gal 2 1/2% HC1 with additives. 1500# 0S90 Unibead diverter 6. Returned well to production immediately upon conclusion of acid job. Completed operations October 22,.1976. 16. I hereby certify that the foregoing ts true and correct TITLE District Engineer DATE October 29, 1976 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY= T IT LE DATE See Instructions On Reverse Side 7= OIL AND GAS CONSERVATION COMMITTEE 'SUNDRY NOTICES AN £PORTS ON WELLS {DO not use thl~, lotto for P.roDosal$ tO dllll Or tO O,,Den Ute "APPLICATION FOR PERMIT-°. for ~ucn Drooosals.) · ,,, O,L ~ oas I---1 WELL I'''! WELLi I OTHER NAME OF OPERATOR I1NION OIL COMPANY OF CALIFORNIA ADDRF. SS OF OPERATOR 909 W. 9th Avenue, Anchorage, Alaska 99501 LOCATION OF WELL At,ur~ac, Conductor #44: 1876'N and 1378'W. frown the S.C. cotter · Section ?.9' T9N, R13W, S.M. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT above MSL Check Appropriate Box To Indicate Nature of Notice, Re .S0- ~, ~ '~E133-20187' DESIGNAT ION AND SERIAL ~O. ADL-18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME TRADING BAY UNIT WELL NO. State G-30 (11-33) ]O. FIELD AND POOL, OR WILDCAT McArthur River Field Il. SEC., T.. R.. M., (BOTTOM HOLE OBJECTIVE) Section 33' T9N, R13W, S.M. PERMIT NO. 69-47 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL {Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other} (NOTE: RePort results of multiple completion on Well Completion or RecomDtetion RePort ancl Log forr~.,~ 35° DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ail pertinent ¢letails, anti give pertinent Dates, inclucling estimatec~ clare o! starting any propos~O work. 1. 2. 3.- Rig up and pull ball valve ~'~11 all gas lift valves Reperforate theW est Foreland Zone as follows' 10828-10838 10860-10875 10883-10913 11080-11130 11180-11220 11265-11300 10712-10727 15' 10' 15' 30' 50' 40' 35' 195' 4. Rerun all gas lift 5. Pdt well on test 6. 7. 8. ESTIMATED STATING DATE valves Rig up pumping equipment and acidize using Dowell Acid Dispersion in diverted stages Immediately re~urnwell to production ~erun ball valve October 18, 1976 ESTIMATED COMPLETION DATE October 21, 1976 hereby certify that the foregoing Is true ancl correct TITLE District Engigeer DATE October 13~ 19'76 CONDIIIONS OF/~I~OVAL. IF ANY~ ' :~ ' See Instructions On Reverse Sido ~, Relumed ~ Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Union Oil and Gas (~' sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union bctober 14, 1976 Enclosed for your approval are three (3) copies of a Sundry Notice for Union Oil Company's well TBUS G-30. The proposed acidizing is a revival of one aspect of a previously submitted and Fpproved Notice dated November 1, 1973. The previous proposal was part of a more involved workover and was not accomplished due to well performance. Sincerely, G. A. Graham District Reservoir Engineer GAG/bb cc: Rodney Smith USGS DI'Vm~ON OF OLL Aht~ n )0/ 02.001B % ,of, ALASKA D~ARTMENT OF NATURAL RESOURCES '- Dirt-sion of Oil and Gas O. K. Gilbreth, Director ' ' ~ ...,~A/ Thru: Hoyle H. Hamilton ~~ O^TE ' April l, 1976 Chief Petroleum Engineer F,Om Russell A. Douglass ~ 0 SUBJECT: Platform inspection, Petroleum Engineering Consultant Union Grayling Tuesday. March 30, 1976 - TraVeled to .the Union Grayling platform. Purpose.of, my trip was-mto' Wi~ne~s Operation of subsurface and.surface safety valves and observe casinghead pressures.', and. production,.tests. , - - Tested a total of 23 surface and subsurface safety valves. All 23 surface safety valves tested okay. Three of the subsurface valves .failed. These. failures were located in wells G-l, G-7, and G-15. Several casinghead pressures in excess of 200 psig were ~.observed. A summary of my observations is attached. I completed a field inspection report which I gave to Bob Smith, production supervisor. I required him ,to repair..or replace, the valves in. we11~ G-l,, .... G-7., and G-15. I also recommended he bleed .down those wells with excessive cas.fnghead pressures. A copy. ~of the ,repor. t is. attached. prbduction test data for the following wells was observed: .Wpl.1 Average oil rate Cut~~% .... G-4 2610 .... .~.- .... 26.0 ...... 32 1536 ~ , 9.5 ... 30 -.. 9.5 30 / 765 .... , In sun,nary i wttnessed safe'ty~'Valve .operations..casi.nghead .pressures, and production tests on the Union Gray].lng,.pla,tform.. failed to operate successful.ly~ Attac.hment Three subsurface ,,safety valves RAO:bJm i ' ........... LL ............. 5 ....... : ........... ~ ....................... /00 .............. · T' .0 )rlg. Permit No. )perator . ~,//,.,~ ~, ~l ,,' ;", ' Well/.Platfm~ Sec T R t.-,~.~,,;~ ,.,~ ,.~ ..... . __ __ Represented by ~,:~, .5,-~/'~.~ Name & Number.. O'~i'~. Alaska Oil and Gas Conservation Committee Field Inspection Report ~atisfactory Type Inspection Satisfactory Type Inspection Yes No Item ( ) Location,General -Yes No Item ( ) BOPE Tests ( ) ( ) --i']. Well Sign ( ) ( ) 15. "Casing set @ ( ) ( ) 2.. General Housekeeping ( ) ( ) 16. Test f'luid-( )wtr.-----~ )mud ( ) oil ( ) ( ) 3. Reserve Pit-( )open( )filled ( ) ( ) 17. Master Hyd. Control Sys.-~_psi,Q ( ) ( ) 4. Rig ( ) ( ) 18. N? btls. , , ,____._psig (.,,):.Sa.fety Valve Tests ( ) ( ) 19 R~mote co--n-~-o~----s (~,~' ( ) 5. Surface-No. Wells ..... ( ) ( ) 20. Drilling spool- "outlets ( ) '(~-)' 6. Subsurface-No. Wells · .z, ( ) ( ) 21. Kill Line-( ).Check valve (,,) Well Test Data ( ) ( ) 22. Choke Flowline ( ) HCR valve (..')' ( ) 7. Well Nos. , , , -,,- , ( ) ( ) 23. Choke Manifold No. valvs fl~s (,,'), ( ) 8. Hrs. obser ~ , .~: ,__, ( ) ( ) 24. Chokes-( )Remote( )Pos.(~dj. ( -),,~ ( ) ( ) 25 Test Plug-( )~.lellhd( ')cs~( )none (-,'")( ) 9. BS&W,, '.> ,,..:~ ,_:_ .... ,__ . .. . ( ) 10. Gr. Bbls.__, ,__,__ ( ) ( ) 26. Annular Preventer, . ..psi~ ( )Final Abandonment ( ) ( ) 27. Blind Rams, psig ( ) ( ) 11. P&A Marker ( ) ( ) 28. Pipe Rams psig ( ) (') 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve .__:~__,Lpsig ( ) ( ) 14. Pad leveled ( ) ( ) 31 Safety Floor valves-( }BV ( )Dart Total inspection observation time ~-/ ,,'l~'~-S)/days Total number leaks and/or ~e(~uip. failures Remarks ,,., ..... .... v,,)?~,,.~: ~., ~.,~' ~:,~ "/ ..:'., ' t ~" ~ ~ ,~ ~" :?.,,z. ,:.~ ~"? ~ ..... ..,. , ,-' ~ .,..,'> :~ ~..':" .~'-~wk: ,~: :~,.:' ,~ ~ X~' ; ,:- '",', .......... ~'~.~' ,:-,~ ,"; ,'i~ "~' ,." .~,, · .L ~..,. , ..... '.,.,"z .r'~:~.,.,:,, ,? ~:~,~...~ ~z.~. / ..... ~'.. ..... '.' ..... :':, ~..' ",?~, ,'-'z!']~, ~ ,.';:' T~ cC. ,,,. ,.',,',,~,..,.' ,,.~,..,? NOtlfy ~n ,~¥ days or when ready Inspected bv i:,' ,[~,,.,~-,r~,,~ Date ..... --r-- . - ...... )'" --~ ~-t-- ,. ' · . . . . · . '.. .... .... '.,. ,~ ' , .,, ' , '" ' . .':'.' :.,";,' ' '' · ~ ',,:"",":,t'~", ,:..''',, ''. , . : · ', , , . ,o,m D-,oo,-, UNIO~ OIL Co. OF CALIFC..%NIA SHEET ., " REPAIR RECORD PAGE NO. I.EASE ...... lrad]3ag_~ay_Lhul_.S~.a~L___WE L NO..G=S0_]~:0COIqTRACTOR F~ELD__.J,~_thur Rive~~ TYPE UNIT_ BEGAN:~i/~y~ COMPLETED: 12/14/73 ELEVATIONS: GROUND_ S.~..~I~.~ R~ort PERMIT NO._fi_q~ SERIAL NO.~18730 CASING HEAD C , ~ .-~ ~ -~ }tess-Watson. OMI A:~Y ENuh'~EER .. / .... TUBING HEAD APPROVED_/,.~<:":' -~ 7 ~..:_~ ~:' '~Z~::.~,-. ~-.-( ~ L~ ROTARY DRIVE BUSHING ~ ..... ~W~~-~ CASING & TUBING RECORD SIZE DEPTH WEIGHT 17 5/4" 13 3/8" 9 s/8" 3 1/Z" 520' 4779' 9866' [1,444' Dual 312 wall 61# 45.5# & 47 29# 9.2# GRADE REMARKS 3piral-wel J-SS N-80-Pll N-80 N-80 J Cmt'dw/ 250 sx. "G" cmt. plug 500 sx. "G" cmt. w/ 2% cac12 Cmt'dw/ 2000 sx "G" cmt plug 200 sx. "G" ont. w/ 2%.CaC12 · 0 Cmt'dw/ 850 sx Bj mix plug 950 sx. "G" cant. w/ 1% CFR2 Liner hanger set at 9785'. ~ See attached detail. PERFORATING RECORD ; INTERVAL ~.T.D. REASON PRESEI~T CONDITION i9 9557-9565 1i,348' Productio]~ Squeezed W/ 200 sx. "G" cmt- 12/2/73. 9588-9610 11,348' Productiol~ Open for Production. 9660-9681 11,348' Productio]1 " " " 9702-9766 Middle Ken;ii "G" Zone " " " 9824-9857 " " " " " 9878 -9892 " " " " " 9956-9977 " " Uhable'"to b?eak-down w/ 6000 psi 12/2/73. ~9 10,712-10,728 " " Open for production. 10,828-10,838 " " " " " 10,860-10,875 " " " " " 10,888-10,891 ,, ,, ,, ,, ,, JAN. 1 7 1974 10,895-10,899 West Forel~md " " " " 10,902-10,914 ,, ,, ,, ,, ,, DI¥1SlON OF OIL ANti _-- _ DAT_E 7/18/ 7/16/69 INITIAL PR()DUCTION AIR DATE I INTERVAL NET OIL CUT GRAV. C.P, T.P. CHOKE MCF GOR REMARKS PERFO', ~ATING ~CORD 0 )NT IAI~E D 7/18/69 11,078-11,150 West Forelmd ProdzctiOn Open for production 11,179-11,216 " ' " " " ~ 11,264-11,299 ,, , ,, ,, I, · . _ WELL HISTORY PRIOR TO REPAIR LAST COMPLETION NO. COMPLETION DATE: 1/7/70 PRODUCING !NTERVAL: Middle Kenai "G" Zone & West Foreland INITIAL PRODUCTION- LAST REGULAR PROD. & DATE: CUMULATIVE PRODUCTION:_ REASON FOR REPAIR:___~[!~u!!_!~2%~Qr repair. Form D-IOO1-B · UNION OIL CO. OF CALIFORNIA ~ REPAIR RECORD /'~ SHEET B PaGE NO. 2 L,.,AoE ..frad_hng_~a; 7J~l+ ~ta~.. COMPLETION DATE: 12/14/75 .WELL NO. G~-30 WOFIELD ,~tcArthur River Field .' I APPROVED DATE DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS TYPE: 6h_~ FF~.r-Cnmernn %WELL HEAD ASSEMBLY CASING HEAD: Shaffer "KD" w/ 2" SE outlets 12" 900 CASING HANGER: Shaffer 12" Nominal 9 5/8" Model kq)KS. CASING SPOOL: TUBING HEAD: -Cameron DC-B12 5000# x 10" 5000# w/ 5000# studded outlets TUBING HANGER: DUal DCB 10" Nominal w/ 3 1/2" x 3 1/2" Buttress on S 3/64". TUBING HEAD TOP' 10" 5000#. Cameron t)~ F gate dual string ooliu block log tree w/ 2-5 1/8" bore.~aster MASTER VALVES: v~_!ves w/ 2-3 1/8" bore wing valves. CHRISTMAS TREE TOP CONN.:. '3 1/2" 2~E 8rd. ...._DATE _ _. 11/27/7:5 11/28/73 11/29/73 11/30/73 12/1/73 12/2/73 12/3/73 12/4/73 12/S/73 12/6/73 12/7/7.3 12/8/73 12/9/73 bELL t{C0l Tradinx Bay Unit State- 11,451 'TD 11 ,~4o 'ETD (Qat. Ret.) ll,451'TD 11,348 ' ETD (Cmt. Ret.) 11,451 'TD 11,348 ' ETD (Cmt. Ret. ) 11,451'T1 11,348 'ET (Cmt. Ret.) 11,451 'TD 11,348 ' ET: (Cmt. Ret.) 11,451 'TD 11,436 'ET] (Cmt. Ret.) 11,451 'TD 11,436'ETI (Cmt. Ret.) 11,451 'TD 11,436 ' ETI (Cmt. Ret.) ll'451'TD 11,436 ' ER] (Cmt. Ret.) ll,451'TD 11,436 ' ETD (Cmt. Ret.) 11,451 'TD 11,436 ' ETD (Ont. Ret.) ll,451'TD 11,436 ' ETD CQnt.' Ret.) t',iELL t'40, c-50 FIELD ~Io~rthur River Field , .D,,ETA. Ii.S. _OF O~E~~__SCR IRT. I QI,!s, & RESULTS (Footage 0') Con~nenced operations on TBUS Well t~G-30' at 12:01 am, 11/27/73. RU Otis and pulled ball valves in. long string and short string. RU Go-Int. and perf. long string from 10,601' to 10,603'. Circ. tubing capacity w/ 70# inven-nul Perf. short string frora 9409' to 9411'. Displaced annulus w/ 7~# inve~,ul. Removed x-mas tree and installed ]~3PE and tested to UOCO specs. Released short string from packer at 942'7' and circ. btms up. Pooh and laid do~m short string 3 1/2" tubing. (Footage 0') 'Completed laying dram 3 1/2" short string. Unable to pull long string. RU Otis ~'~%. Pulled 9 gas lift valves in long string. RU Go-Int. Ran free pt. and fo~md tubing in long string. Free to 10,605'. Cut long string tubing at 10,605' (16' above btm~. hyd. pkr.) (Footage 0') Pooh w/ long string. Laid dram 3 1/2" tubing and accessories. Fish left in hole - 1 cut jt. of 3 1/2" tubing, 18.35' above Guiberson 7" x 3 1/2" RH-1 packer. (top of fish at 10,602'TH.) Ran 6" shoe, 5 3/4" wash-over extensions and 5 3/4" x 3 1/2" overshot on 3 1/2" and 5" DP to top of sand fill at 10,589'. Washed doan to packer at 10,621'. Engaged tubing fish at 10,602' and jarred free. Pooh w/ fish. (Footage 0') Finished Pooh w/ fish. Rm~ in hole w/ 8 1/2" bit and 9 5/8" csg. scraper to top of liner at 9785'. Ran 6" bit and 7" csg. scraper. (Footage 0') Tagged sand fill at 11,200'. CO to 11,348' and drilled to 11,436' due to DPM error. Pooh. Rigged up k~. Ran guage ring and junk basket to 10,200' Ran 5~. bridge plug and set at 9995'. Ran ¥~.L cement retainer and set ~t 9920'. Ran DP and stabbed into retainer at 9920' to squeeze '%" Zone Bench #6 perf. from 9956' to 9977'. Unable to break perfs, w/ 6000 psi.' , (Footage 0') Pooh w/DP. Set ~L bridge plug at 9575'. Ran cement retainer on DP mhd set at 9450'. Broke down "G" Zone Bench #I perfs, from 9537' to 9563' w/ 2200 psi. Pumped in at 2200 psi at 8 cfm. Formation lteld 2000 psi w/o pmtp. Mixed 200 sx. Class "G" cement. Squeezed 200 sx. below retainer to a nmximum and final pressure of 3200 psi. Pressure bled to 2700 psi in 5 min. (Footage 0') Completed Pooh w/ retainer setting tool. Repaired hydromatic brake. TIH w/ 8 1/2" bit. Tagged cement retainer at 9450'. (Footage 0') Drilled cement retainer at 9450'. Drilled firm cement to 9465'. b~de bit trip. Drilled cemm~t to btm. of Bmmh #1 perfs at 9563'. Tested perfs from 9537' to 9563' w/ 2500 psi. Held ok. Drilled bridge plug at 9575'.- CO to top of liner at 9785'. (Footage 0') Till w/ 6" bit. Drilled renminder of 9 5/8" retainer on top pf 7" liner at 9786' TIIi to top of retainer at 9920'. Drilled 7" cement retainer and pushed ~o top of bridge plug at 9995'. blade bit trip. (Footage 0') Drilled on cement retainer at 9995'.. Pooh for new bit. Drille on cement retainer and junk at 9995'. Pooh and ran,concave mill. (Footage 0') Milled 7" retainer out at 9995'. Pushed to ETD at 11,436'. Circ. and cond. invemnul. Pooh w/ mill. RU electric line unit. P~nn guage ring and junk basket to 11,000'. (Footage 0') Rm~ Baker Model "F" 7"x 3 1/2" perm. production packer and set at 10,621'. Ran packer seals on 3 1/2" and 5" I)P. Tested production packer at 10,621' w/ 1200 psi ok. Pooh. Laid do m 5" and 3 1/2" DP and collars. (Footage 0') Completed laying down 5" and 3 1/2" DP and collars. RU to run 3 1/2" dual strings of.Production tubing. LUNSE Trading~ Bay Unit State ELL I LCOI D WELL I",lO, c-3o FIEU) Mc~rthur River Field 12/10/73 12/11/73 12/11/73 12/13/73 12/14/73 D~T^!LS OF_OPER_NkT_.LO~S.___Q_ES_CJZjP_T!pJ~S_' & RE SULJ__S.__ ll,451'TD (Footage 0') Completed running 3 1/2" dual string production tubing. ll,436'EqTD Landed 3 1/2" tubing on I.~ packer at 10,629'2~I. Rigged up Schlumberger and ran collar locator in long and short string' t0 check location of gas lift mandrels. ., ll,451'TD (Footage 0') Compl'eted spacing out tubing and running ball valves. Removed 11,436' BOP's. Installed and tested x-mas tree. ll,451'TD 11,436 (Footage 0') Completed displacing invermul w/ diesel. Set plug in "Q" nipple in short string. Set dual hydraulic packer at 9409'-tested ok. Ran gas lift valves and ball valves in short string. ll,451'TD (Footage 0') Completed running Otis gas lift valves in long string 11,436 ~Note: Sho~t string shut-in until long string is unloaded. ll,451'TD (Footage 0') Completed unloading long string tubing. Started unloading 11,436 short string. Ail equipment - ok. Completed operations at 12:00 Midnite, 12/14/73. Released rig for de-activation operations. LEASE Trading Bay Unit State · WELL I<LCOI . WELL i',lO, G-30 WO FIEU') ~:lcArthur River Field p_E_TA4~L~__OF O?ER TATj~JJS,= DESC_B_ P~.~P_I ~E_S._U_~I.C~ ..... TUBING DETAIL LONG STRING JTS. LENG~-t BOTTO~ TOP 0.75 10,661.23 10,660.48 1.35 10,660.48 10,659.13 10.06 10,659.13 10,649.07 20.16 10,649.07 10,628.91 .85 10,678.91 10,628.06 30.58 10,628.06 10,597.48 3.85 10,597.48 10,593.63 972.17 10,593.63 9,621.46 ?8.78 9,621.46 9,542.68 122.99 9,542.68 9,419.69 9.85 9,419.69 9,409.84 4.08 9,409.84 9,405.76 31.47 9,405.76 9,374.29 4.78 9,374.29 9,369.51 304.28 9,369.51 9,065.23 4.78 9,065.23 9,060.45 793.71 9,060.45 8,266.74 4.78 8,266.74 8,261.96 826.80 8,261.96 7,435.16 4.78 7,435.16 7,430.38 270.28 7,430.38 7,160.10 2.12 7,160.10 7,157.98 512.89 7,157.98 6,645.09 4,78 6,645.09 6,640.31 818.01 6,640.31 5,822.30 4.78 5,822.30 5,817.52 792.69 5,817.52 5,024.83 4.78 5,024.83 5,020.05 862..97 5,020.05 4,157.08 4.78 4,157.08 4,152.30 828.09 4,152.30 3,324.21 4.78 3,324.21 3,319.43 758.76 3,319.43 2,560.67 3 1/2" khale Shoe 3 1/2" Otis "Q" Nipple (ID-2.625") 3 1/2" 9.2# N-80 Pup Jr. Baker Seal Assembly Locator Sub 3 1/2" 9.2# N-80 Buttress Tubing 1 3 1/2" Otis t'XA" Sleeve (2. 750"ID) 3 1/2" 9.2# N-80 Buttress Tubing 32 3 1/2" Blast Jts. (4) 3 1/2" 9.2# N-80 Buttress Tubing 4 9 5/8" x 3 1/2" x 3 1/2" Otis dual hTdraulic packer 3 1/?' 9.2# N-80 Buttress Pup Jr. 3 1/2" 9.2# N-80 Buttress Tubing 1 3 1/2" Otis "CX" khmdrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 10 3 1/2" Otis "CX" Mandrel (2.~13"ID) 3 1/2" 9.2# N-80 Buttress Tubing 26 3 1/2" Otis "CX" Mandrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 27 5 1/2" Otis "CX" Mandrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 9 3 1/2" 9.2# N-80 Buttress Pup Jt. 3 1/2" 9.2# N-80 Buttress Tubing 17 3 1/2" Otis "CX" Mandrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress ~bing 27 3 1/2" Otis "CX" ~'~andrel (2.313" Il)) 3 1/2" 9.2# N-80 Buttress Tubing 26 3 1/2" Otis "CX" Mandrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 28 3 1/2" Otis "CX" Mandrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubh~g 27 $ ,1/2" Otis "CX" Mandrel (2.313"ID) 3 1/2" 9.2# N-80 Buttress Tbg. 25 3 1/2" Otis "CX" Mandrel LEASE Trading Bay Unit State .WILL ltCOl-~D .. WELL 1'40, ~-~o Wo FI[~) McArthur River Field DETA. I L~I~S~_~y__LO];I$_. ?; .RE_S_UI~FS ....... TUBING DETAIL LONG S~lllNG (cont..) 3 1/2" 9.2# N-80 Buttress Tubi~lg 3 1/2" Otis Ball Valve Mandrel ~TYrr~ 3 1/2" 9.2# N-80 Buttress Tubing 3 1/2" 9.2# N-80 Pup Jr. 3 1/2" 9.2# N-80 Pup Jr. 3 1/2" 9'~2# N'80 pup Jr. 3 1/2" Cameron Tubing Hanger Landed Below Zero JTS. LFAIG~t BOTT~'I TOP ,, ,, _ , -- : , ...... , ~ i, ,,, - -- ~- 75 2,245.93 2,555.89 309.96 4.20 ~09.9 243.08 305.76 62.68 10.05 62.68 52.63 10.13 52.63 42.90 3.40 42.50 39.10 , 1.00 39.10 38.10 38.10 38.10 -0- WELL [~SE rd~~ay U~_~ State_ ~E DgTA.IL.S OF OpER~L~SCR_LIP_T..I_OJ']S & RESUL:FS TUBING DETAIL SttORT STRING 3 1/2" Otis "Q" NipPle (2.625" ID) 3 1/2" 9.2# N-80 Buttres.i Pup Jt. 9 5/8" x 3 1/2" x 3 1/2" Otis dual hydraulic packer 3 1/2" 9.2# N-80 Buttress Tubing 3 1/2" Otis "CX" Mandrel (2.313" ID) 3 1/2" 9,2# N-80 Buttress Tubing 3 1/2" Otis "CX" ~mdrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 3 1/2" Otis "CX" b~mdrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 3 1/2" 9.2# N-80 Buttress Pup Jr. 3 1/2" 9.2# N-80 Buttress Tubing ' ' 3 1/2" Otis "CX" Mandrel (2.$13" ID) 3 1/2" 9.2# N-80 Buttress Tubing 3 1/2" 9.2# N-80 Buttress 'Pup Jr. 3 1/2" 9.2# N-80 Buttress Tub lng, 3.1/2" Otis "CX" b~mdrel- (2.31~" ID) 5 1/Z" 9.2# N-80 Buttress Tubing 3 1/2" Otis "CX" ~kndrel (Z. 313" ID) 3 1/2" 9.2# N-80 Buttress Tubing. 3 1/2" Otis "CX" b~tndrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 3 1/2" Otis "CX" b~drel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 3 1/2" Otis "CX" b~ndrel (2.313" ID) 3 1/2" 9.2# N-80 Buttress Tubing 3 1/2" Otis "CX" Nhndrel (2.313"ID) 5 1/Z" 9.2# N-80 Buttress Tubing 3 '1/2" ~ve bhndrel (2.31:- ID) - - - -- 3 1/2" 9.2/t N-80 Buttress JTS LENGTH BOTTOM TOP 11 25 10 17 24 2 27 26 28 27 25 73 1.35 10.08 9.85 29.01 4.78 355.79 4.78 764.71 4.78 307.99 4.50 514.92 4.78 728.79 3.02 60.99 4.78 811.54 4.78 793.11 4.78~ 860.51 4.78 824.63 4.78 771.66 4.78 2243.33 4.20 ?dZl dq 9432.87. 9431.52 9451.52 9421.44 9421.44 9411.59 9411.59 9382.58 9382.58 9372.80 9377.80 9042.01 9042.01 9037.23 9037.23 8272.52 8272.52 8267.74 8267.74 7959.75 7959.75 7955.25 7955.25 7440.33 7440.35 7435.55 7435.55 6706.76 6706.76 6703.74 6703.74 6642.75 6642.75 6637.97 6637.97 5826.43 5826.45 5812.65 5821.65 5028.54 5028.54 '5023.76 5023.76 4163.25 4163.25 4158.47 4158.47 3333.84 3333.84 3329.06 3329.06 2557.40 2557.40 2552.62 2552.62 509.29 305.09 ~O5.O0 60.60 'wELL I<LcoI [~[ ...... Trad, ing Bay Unit State DB!A._I_kS OF O__PE~~E__SF.j~ P'__Er!PJf,~ ~_8~_E_'_s_.uiJ_s__~ ~ TUBING DETAIL SHORT STRING (cont..) JTS. LENGTH BOTT(lX~ TOP 1/2" 9.2# N-80 Buttress Pup Jt. 1/2" 9.2# N-80 Buttress Pup Jr. 1/2" 9.2# N-80 Buttress Pup Jt. 1/2" Cameron Tubing }{anger 10.'03 60.60 50.57 10.12 50.57 40.45 1.45 40.45 39.00 '1.00 38.00 -0- Zero Datum Tubing hanger _ -- i i ii i ii IL TUBING DATA-LONG STRING' 3 1/2" 9.2# N-80 Buttress tubing w/ tail at 10,661'. TUBING DATA-SHORT STRING' 3 1/2" 9.2# N-80 Buttress tubing w/ tubing tail at 9433'. GAS LIFT VALVE DATA LO;qG' 'ST~-ING ' 3 1/2" Otis "CX" Valves at 2556' 3319' 4152' 5020' 5818' 6640' 7430' 8262' 9060' and 9370'. SHORT STRING: 3 1/2" Otis "CX" Valves at 2553', 3329', 4158' 5024' 5822' 6638' 7436' 8268' 9037' and 9373'. 4779'-13 3/8" 61# J-55 Buttress Csg. 9$09'-Otis 9 5/8" x 3 1/2" x 3 1/2" dual hydraulic packer. 9785'-7" Liner top. 9866'-9 5/8" 45.5# & 47# N-80 & P-l: Buttress Csg. 10,621'DIL-Baker Model "F" 7"x 3 1/2" permanent packer. TD 11,451 , " ' e - , 11.444 - 7 29# N-80 Buttress L~n:. ETD 11,430 ' - ~ DRAWN C, KD. DAT~ A~P'D, T~ING ~Y ~IT ~ATE ~LL G-30. ~L~ ~ [ . . . ~~ ~ ' 12/11/73:~ ~ -- ...... ~ I )l'~ Oil g~ 'i'.4~ r~NY O, G,~LJ/O,,N ~ I sHr,:'s J:O[{M 24'/ [t~EW 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.) 5. APl NUMERICAL CODE 50-133-20187 6. LEASE DESIGNATION AND SERIAL NO. ADL-18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME UNION OIL COMPANY OF CALIFORNIA Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 909 West 9th Avenue, Anchorage, Alaska 99501 State G-50 (11-55) 4. LOCATION OF WELL At su~ace Conductor #44: 1876'N ~ 1578'W from the S. F.. corner. Section 29 :T9N, R15W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99 ' RT above MSL. 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 33: TgN, R13W, S. H. 12. PERMIT NO. 69-47 )ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Squeeze off wtr. entry. ., (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. Squeezed off water entry in the G-1 and G-6 Sands. 11/27/75. Operations were completed at 12:00 Midnite, 12/14/75. Commenced operations at 12: 01 am, 1. Moved rig over well. Killed well w/ Invemul. 2. Installed and tested BOP's. 5. Pulled tubing and packers, (dual string). 4. Cleaned out to ETD at 11,548'. 5. Straddled perfs at 9956' to 9977'.and tested. 6. Straddled perfs at 9537' to 9563'. Squeezed and tested. 7. Cleaned out to ETD. 8. Ran dual tubing strings w/ dual packers and gas valves. 9. JAI' 0 i 374 Changed over to diesel, set packers and returned well to production. *Note: The acidizing of the West Forelands w/ 12-10 HCL-HF acid as/programed is pending on production testing. 16. I hereby ce.~that the foregoing is true and correct S'GN~7/ Jim R. Caiiender District Drlg. Supt 1/5/74 TITLE ' DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.- TITLE DATE See Instructions On Reverse Side Form No. P---4 l~"V, STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMrT I~N ~JI~LICA~ MONTHLY RE!PORT O'F ~DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAM.~. OF OPI~:~ATOR UNION 0IL COMPANY OF CALIFORNIA 3.ADDRESS OF' OPER,A'I'OR ..... 909 West 9th Avenue, Anchorage, Alaska 99501 4 LOCA~O~' OF WF~L Conductor #44' 187§'N ~ 1578'W from the S. E. corner. Section 29' T9N, R13W, S. M. ~Ai~I N~J"A~.ERICAL ~ODE 50-155-20187 LEASE DESIGI~ATION A.~D SErI~IAL NO. ADL-18730 IF INDIAN, AL~DT1-EE O~ TRIBE NAME 8. LL'IT FA.I'iN[ OR LEASE N~ME Trading Bay Unit 9 WELL NO State G-30 (11r33) 10 FL~;i.D A_ND POOL. OR %VILDCAT Mc. Arthur River Field -11 SEC, T.. R.. M. 0~O~UTOM HOI~ o~ Section 53: TgN, ~3W, S. M. 12. I~IgP, lVl IT 69-47 13. REPORT TOTAL DEI~TIq AT F~D OF MaNn'ri. CI4~'qGES IN HOLE SIZE, CASING A~ C~NG JOBS INCLUDING DEP~ SET ~ VOL~ USED, P~O~TIONS, ~STS ~ ~SULTS ~SHING JO~ J~K ~ HO~ AND SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~N~ITIONS Commenced operations at 12:01 am, 11/27/75. Operations from the 1st of December through completi0h are as folloWS: Ran WL bridge plug and set at 9995'. Ran WL cement retainer and set at 9920'. Ran DP and stabbed into retainer at 9920' to squeeze "G" Zone Bench #6 perfs, from 9956' to 9977'. Unable to break down perfs. w/ 6000 psi. Pooh w/ DP. Set WL bridge plug at 9575'. Ran cement retainer on DP and set at 9450'. Broke down "G" Zone Bench #I perfs, from 9557' to 9565' w/ 2200 psi. Mixed 200 sx. Class "G" cement. Squeezed 200 sx. below retainer to a maximum and final pressure of 5200 psi. Cleaned out to ETD at 11,456' Circ and cond. invermul. Ran Baker Model "F" 7" x 5 1/2" perm. production ~kr. an~ set at 10,621-tested to 1200 psi-ok. Pooh. RU ~& ran 5 1/2" dual strings of production tubing. Landed 5 1/2" tubing on WL packer at',. 10,629'TM. Rigged up Schlumberger and ran collar locator in long and short string to check location of gas lift mandrels. Completed spacing out tubing and running ball valves. Removed BOP's. Installed and tested x-mas tree. Displaced invermul w/ diesel. Set plug in "Q" nipple in short string. Set dual hydraulic packer at 9409'-tested ok. Ran gas lift valves and ball valves in short string, and long string. Returned well to production. ~eratio.ns were completed at 12:00 Midnite, 12/14/73. *Note: Thegn productionaCidizing Oftesting.the West Forelands w/ 12-10 HCL-HF acid~as/pro~r ~am~~ ~ ~ ~l ~~~~ing ~ ~, ,~~'---~--- =~ District Drl~. Supt. ,, .~ 1/5/74 ~Report on this f~m il required for ~ calender ~thT regardless of the status of operations, and must ~ filed indupli~te with the oil and got cofllervQtbfl commiflee by fha 15~ of the suec~diflg ~fl~, ~IeK ofherwile d~re~ted, Union Oil and Gas D~ion: Western Region union December. 6, 1975 Union Oil Company o ~.,.,,-,lifornia 909 W. 9th Avenue, Anchorage, Alaska 991~01 I r)lR / / Telephone: (907) 279-7681 Mr. Homer BurrelI Division of Oil & Gas State of Alaska 3001 Porcupine Dr. Anchorage, Alaska 99504 RE: TBS A-221 P-4 _ }j¢~ l:l~a,t.- 14~'~/'-~"--" <,T us vp ? . TBUS G2~6 P-4 - ~ ~' ~j - ~ TBUS G-6 P-5 ~ P-4 COttOE ~IT ~ I P-4 _ Dear Mr. Burrell' Enclosed please find the appropriate number of copies for the above captioned forms for the above captioned wells. Very truly yours, District Drilling Supt. sk Enclosures (14) Form No. REV. STATE OF ALASKA SUBMrr IN nvPucA~'z OIL AND GAS CONSERVATION COMMI~EE MONTHLY RE!PORT O'F ~DRILLING AND WORKOVER OPERATIONS APl NU~{EmCAL ~oDE ' 50-155-20187 LEASE DESIGNATION AND SEHIAL NO. ADL- 18730 1. 7.IF INDIA]~', ALOTT~E O]~ TRIBE NAME OIL ~X~ GAB [] OTHER WELL WELL 2. NAME OF OPEP,~TOR UNION 0IL CCbtPANY OF CALIFORNIA 3. ADDRESS OF OPEI~ATbR 909 West 9th Avenue, ;mchorage, Alaska 99501 4. LOCATION OF WELL Conductor 44: 1876'N ~ 1578'W from the S. B. corner. Section 29: TgN, R15W, S. M. 8. LrNIT,FAP~M OR LEASE NA~ME Trading Bay Unit 9. WELL NOr G-50 (11-55) 10. FIF-J~D AND POOL. OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BO~TOM HOI~E o~ Section 33: TgN, R15W, S. M. 1~-. PERMIT NO. 69-47 ]3. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOLLrI~ USED, PF_~OP~ATIONS, T~.STS AN-D YLESULTS. FISHING JOBS. JLrNK IN HOI~E ~ND SIDE-/-RACKED HOLE AND ANY OTHER SIGNIFICANT CI-IA~-~ES IN HOL~ CONDITIONS. Comuenced operations on TBUS Well G-30 at 12:01 am. 11/27/75. Killed well w/ 70# Inve~l. Pulled 5" i/Z" huai tubin~-~trings'"'Knd'C~ well to' ETD at 11,465'. Now: Prep. to squeeze for water shut-off. 14. I hereby c~r~fy that the.,~oreg~g is true and eozTect s,a~~..~~- _~u~ Dist. Dril~. Sunt. o^~. 12/5/73 ~ NOTE--Report on this form is required for each calendar month, r e9ardless of the status of operations, an~ must ~ filed in duplicate with the Division of Mines & Minerals by t~ lSth of the succeeding month, unless othe~ise directed. FormREV. 9-30-69P--3 ~ & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION: COMMITTEE · 6. I~E D~GNATION A-ND SJ~P. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposms ~o drm o~ to d~e~ ~. 2. NAME OF OPE~TOR 8. UNIT, FA~ OR L~SE NAME ~ION 0IL C~~ 0F ~IF0~ Trading 3. ADDRESS OF OPERATOR 909 West 9th Avenue, ~choraKe, ~as~ 99501 State G-30 (11-55] 4. LOCATION OF W~L 10. F~ ~D ~t~u,~c~ Conductor t44: 1876'N ~ 1378'W from the S. n. s~c., T., ~,, M., (~OM ~O~ co.er, o~v~) Section 29: T9N, ~5W,. S.M. Section 55: T9N, R15W, ............................. ~- ~ ~m ~ =+. 12. P~T NO. 13. ELEVATIONS (Show 99'RT above MSL. 14. Check Appropriate Box To Indicate N;t'ure of NOtice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE PULL OR ALTER CASING MULTIPLE COMPI,ETE ABANDON' CHAN(]E PLANS 69-47 ~ort, or Other D~a ' eUBSEQUENT REPORT OF: SHOOTING OR ACIDIZINO ABANDONMZNT' (Other) REPAIR ',','ELL J-- (NOTE: Report reaults of multiple completion on Well ,O~h~r~Squeeze off wtr. entry. ! , Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all' pertineut details, and give pertinent dates, including estimated dato of starting any proposed work. To squeeze off water entry in the G-1 and G-6 Sands and acidize the Weitt Foreland Sands in well TBUS G-50. 1. Move rig over Well. Kill well w/ Invermul. 2. Install and test BOP's. NOV 8 1973 3. Pull tubing and packers, (dual string). 4. Clean out to ETD at 11,348'. 5. Straddle perfs at 9956' to 9977'. Squeeze and test. ANL'itflRA.gp 6. Straddle perfs at 9557' to 9563'. Squeeze and test. 7. Clean out to BTD. 8. Run dual tubing strings w/ dual packers and gas valves. 9. Change over to diesel, set packers and return well to production. 10. Acidize We-~t Foreland w/ 12-10 HCL-HF acid. BSTI~tTBD C(NPLETION TIMB Eighteen (18) Days. l~/Ff~reby certify that the fore$o{n~-ie true and correct SIGNED v'-- r, ,",--'~ '~ ----J--~ TITLE (This ,pace for StatUte use) "/ - CONDITIONS ~F~PPBOVAL, IF District Drillin~ Supt. DATE 11/1/75 See Instructions On Reverse Side Approv~.:t CbOe: Returned .fA PERFOIIITIONS - P~SE~'7 CON~DITION Benches "G" ZO:~qJ 9557".-9563' 9588'-9610' 9660'-g681' 9702'-9766' 9824'09857' 9878'-9592' 9956'-9977' WF I02-7 WF ~ 03-8 WF 105~8 WF 106-8 WF IO7'6 t~ST FOREL,~D 10;712'-10,728' 10,828'-10,8S8' 10,860'-10,875' 10,883'-10,891' 10,B9S'-10,899' 10,902'-10,914' 11,078'-!!,!30' 11,179'-11,216' 11,264 '-11,299' .J NOYB 1973 I)I~ION Or 011, AND GAS ANCIIOR A~,r, UNION OIL CO. Of CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE Tradinq Bay Unit State DATE E. T. D. WELL NO. G-30 FIELD McA[.thur River DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS -' i 12/10/69 ball v~ 11 13 lye Otis Engineers RU to install gas lift valve in short string, well TBUS G-30 (MiddleKenai "G" Sands). Tbg ~vas preSsd to 1000 psi above subsurface ball valve at 290' prep to pulling said valve. When ball valve was pulled from mandrel, diff press blew the valve, pulling tools & sinker bars up the hole & caused them to foul in xmas tree. The fouled tools prevented closing any valves on the xmas tree as well as the wireline valve on the lubricator. The impact caused an O-ring seal on the lubricator to fail, & a leak developed. Press on the lubricator was 2900 psi, gas was escaping into well head room ~2, & Willis automatic valve on flow line failed, closed? leaving no way to close well in or vent gas except thru the leak in the lubricator. At this time, drilling operations on G-I2RD were suspended & all wells .were SI. All electrical devises;not essential to operations were shut down. Otis Engineers attempted to freeze base of lubricator, but were unsuccessful being unable to spot fluid in the desired area. The attempt at freezing caused a fracture in base of lubricator & a subsequent leak from the fracture. RU Go-International on Long String in attempt to peri tbg between pkrs. Were unable to get guns thru ball valve in long string. Gas still escaping into wellhead room. Manually opened Willis Auto Valve on flow linej This released pressure on lubricator. Pressure dropped to 30~ 4--) Utilizing ~ Chaffer adj.ustably choke stem flanged to valve. RU Dia Log on Long String & RiHw/string shot to split tbg. TP fell 200.~when shot discharged @ 9966'. RU & produced thru both strings in attempt to draw down pressure on short string. Baker locked saddle clamp around leak in lubricator & welded fracture in swage at base of lubricator. RU halliburton unit on short string thru top of lubricator & pumped ball valve open w/3000~. · Pumped down short string w/reFrns from long string. Pumped 460 ft3 of water' 30 ft3 diesel, & 1250 ft of invert emulsion mud @ 76f~down short string killing pressure. Removed Otis lubricator & cut off tools at top of bree. Installed Halliburton valve on short string & installed new Willis Hi-Low valve on lead line. Closed well in w/400~ on long string & 0.~ 3n short string @ 6:00 pm 12/13/69. NOTE: Bubble Point of Middle Kenai "G" oil is 3810~. Orig BHP was 4000¢¢. rhe pressure just prior to this. incident was 3650~ resulting in gas break & pressure build up to near bottom hole 1 pressure at the surface. qNY FUTURE OPERATION MUST BE PLANNED TO WORK WITH THIS PHYSICAl] CONDITION. LUBRICATORS ON SHORT STRING (MIDDLE KENAI "G" ZONE) ~IDE OF DUAL COMPLETIONS MUST BE PRESSURED TO 3000¢r PRIOR TO PULLING BALI, VALVES. DIVISION OF UNI.ON OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PA(~E NO. I-- LEASE Trading Bay Unit State , WELL NO. G-,.30 FIELD McArthur River Field DATE 1/2/70 E. T. D. 11345' 11345' DETAILS OF OPERATIONS, DESCRIPTIONS 8c RESULTS RIG RELEASED from G-12 R.D. @ 12:00 Noon 1/2/70. Moved to G-30 & RU. Otis pulled ball valve & opened XO sleeve ~ 9385'. ,2irc & kill well w/77~ invert emulsion mud. Install B.P.V., remove tree, install riser & NU BOP. Change rams to 3-1/2" dual. POH & I.d. damaged 3-1/2" tbg. String shot fired in long string on 12/12/69 had split tbg 18". RIH w/da & CC) to ETD. Circ @ 11345'. POH. Instld dual 3-1/2" pipe rams in BOP & started rng dual string of 3-12/" tbg. Ran & landed 650 jts & 1 pup jt of 3-1/2" buttress 9.2~, N-80 tbg as dual string @ 10,664'. Guiberson 7" single RH-1 pkr @ 10,621' & 9-5/8" dual RH-2 pkr @ 9427' & Otis "CX" & "XO" sleeves per tbg detail. Removed BOP's & NU & test tree to 5000~. Displaced invert emulsionmudw/28000 gals diesel. Set pkrs & tstd OK. Shut well in & turned over to production. RIG RELEASED @ 9-00 am 1/7/70 to move to G-9', ""~'~- ' '' ' ~ FOR . ; COMPANY TELEPHONE DATE NAME WELL NAME COUNTY jSTATE [] NEW SIZE W El GHT ,ir ~RADE. TH READ DEPTH SIZE WEIGHT GRADE THREAD DEPTH Q SAFETY EQUIPMENT (~) GAS LIFT EQUIPMENT O PACKERS AND ACCESSORIES OCOMPLETION EQUIPMENT O POST COMPLETION EQUIPMENT DESCRIPTION OF EQUIPMENT AND SERVICES .~ ¥~:'. I/.) , 5', 3", 7c lilY. i I i TOTAL ESTIMATE COMPLETION PROCEDURE ESTIMATE 373¢.7~ 717/ ¢'Z. ~3~1,~7 PREPARED BY WELL NAME r-,~.., OFFICE TELEPHONE I 1 FIELD NAME ' DATE ~l~rlll~ ?'~ ~Jl~f Il Il ' -- ~------" ~~~'--' I - ' R ! , ' I PREPA,_ · ~/'FO COMPANY TELEPHONE t I · I I /~'~ -" MR,. U?,'~ ,. C,/ c , ! ,/:/, j FIELD NAME WELL NAME · COUNTY .$TATI~ D NEW COMPLETION ~ [] WORKOVER SIZE WEIGHT THREAD DEPTH c^S,NG ¢~.- SIZE WEIGHT GRADE THREAD DEPTH · '"" I ~" I I I (~ SAFETY EQUIPMENT (~)GAS LIFT EQUIPMENT OPACKERS AND ACCESSOR4ES OCOMPLETION EQUIPMENT 0 POST COMPLETION EQUIPMENT DESCRIPTION OF EQUIPMENT AND SERVICES Z./,~. · .5'. 76 I~!~,., 52 5-. 7c ..~', 74. i .5. ?.~ d', I. SI. Co q, ;c /2,5'_~ 3,7c... 2c, c/,7 ~,7X 3c,?~... TOTAL EST v~ATE ESTIMATE 373.~. 77 Z ~'¢. ~./ SI ?q2Zgl /¢, y,',r4.. 37 ! OFFICE TELEPHONE FIELD ~IAME DATE - .>//: ,4../," /~,, .,. //-/''': TO' FROM' UNION OIL & GAS DIVISION WESTERN REGION ANCHORAGE DISTRICT STATE OF ALASKA 'G. H. Laughbaum, Jr. TRANSMITTAL DATE. 10/3/69 WELL N~IE' TBU Transmitted herewith are the following: Run No. Final Sepia Blue Scale I i Induction Electrical Log --2~ Dual Induction Laterlog BHC Sonic/Caliper Log BHC Sonic/Gamma Ray BHC Sonic/Caliper/Gamma Ray Log Formation Sonic Log (Fs) Compensated Formation Density Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) High Resolution Dipmeter (HDT) CDM Safety Print CDM or Printout CDM or Polywog Plot CDM Polar Plots Proximity Microlog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log Sidewall Neutron Porosity Log Laterlog 3 Mud log Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analysis Formation Tests Directional Surveys Core Chips Sample Cut DIW$1ON OF O1£ AND_ GAS RECEIPT ACKNOWLEDGED' RETUPuN RECE ! PT TO' Union Oil & Gas Division - Western Region Anchorage District P. O. Box 6247, Airport Annex Anch~-r~ A~aska 99503 Attn: Rochelle Carlton STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OTHER NAME OF OPEI:~TOR Union Oil COmpany of California 507 West Northern Lights Blvd., Anchorage, Alaska 99503 4'~ON OF WELL --'"--- Conductor #44, Leg #2, 1876'N & 1378'W from SE corner Section 29, R13W, SM. APl NL'A.'iEP,/CAL CODE 50-133-20187 ADL 187230 Trading Bay Unit State G-30 (11-33) ~,, _ - ml~ ~enai G McArthur River - West Foreland I.i. SEC., T., R., ~,~., C~OTTO,X~ HOLE O~-ZCTrVE) Section 33, T9N, R13W, SM. 12. P~IT ~O, ~ . .., .. 69-47 13, REPORT TOTAL DEPTH AT END OF MONTH, CI-IA~%'GES IN HOLE S E1VIENTING J'~BS SET A/WI) VOLU/VIF~ USED. PERFORATIONS. TESTS A_ND RESULT~ _ INCLUDING DEPTH AND ANY OTHER SIGNIFICANT CI-IA/~G~ IN HOL~ CONDITIO ........... .,_,o~. Jump,. LN HOLE AND SIDE-TRACKED HOLE :~I'¥1$ION OF OIL AND GAS TRAD____ING BAY UNIT STATE G-30, J~ULY 1969 ANCHORAGE, While rng -5/8 csg, it stuck w/shoe f 9866'. Cmtd thru shoe w/850 sx ,! o "G" with 1/2 cu. ft. perlite per sk & 6% gel followed by 950 sx "G" w/l% CFR-2. CIP 3:00 p.m. 7/1/69. WOC 12 hrs. NU. PU d.a. Tstd blind rams OK. RILL. Drld float collar @ 9818'. Tstd pipe rams & hydril OK. Drld shoe @ 9865' & firm cmt to 9890'. Drld to 11,451'. Circ & condition for logs. Ran Schlumberger DIL, Sonic, Density, & HRD logs. Sidewall sampled. RI w/ d.a. to 11,451'. Circ & condition hole for lnr. PO. Ran 40 its 7" 29# N-80 buttress csg on TIW lnr hngr. Hung w/shoe @ 11,444' top of hngr @ 9785'. , Ran Schlumberger perfng gun. Shot four 1/2" holes above float collar in 7" lnr @ 11,375'. Ran 7" Howco EZ drill cmt retainer. Set @ 11,349'. Broke circ @ 2700#. Circ thru perfs around lnr. Cmtd lnr w/lO00 sx "G" w/CFR-2. PO of retainer, dumped 15 cu.ft, cmt on top of retainer. CIP 6:00 p.m. 7/10/69. Reverse circ clean. Ran Howco 9-5/8" retrievable BP & set @ 914'. Remnv~d R0F In-t ll ' , l"orm No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ~UBMIT IN DUPLICATE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS 4. LOCATION OF WELL ~. API NUA{EKICAL CODE -- ~~r~ OR LEASE ~ ~11. SEC.. T., R., M.. (BO'I~FOM HOLE OBJ'~IVF_J 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA~%'G~ IN ~OLE SIZE, CASING ANT) CE1ViEN~NG JOBS INCLUDING DEPTH SET AND VOLUMES USED, PER. FO'~TIONS, TESTS ANT) RESULTS. FISHING JO~. JUWK ~ HOLE AND SIDE-TRACKED HOLE A_ND ANY OTHER SIGNIFICANT CI-I.A~G~ ~ HOI~ CONDITIONS. TRADING BAY UNIT STATE G-30,~.:~JULY !.969 (c.ontinu~d~) ~quee~e Job #2: Stabbed into retainer @ 10,600'. Pumped 100 cu.ft, wtr3 followed by 200 sx 1% CFR-2 "G" cmt mixed w/fresh wtr followed by 50 ft wtr. Closed tool on 100 ft3 wtr. Sqzd for 2 hrs 30 min. ax build up 4800#. Would not stand above 4400#. Cleared holes w/33 ft~ wtr. Pulled out of cmt retainer. Circ. CIP 10:00 p.m. 7/13/69. Stabbed into retainer @ 10,600'. Pressured to 5000#, held 15 minutes OK. POH. Schlumberger shot four 1/2" holes in 7" lnr @ 10,020' (top Hemlock). Set EZ drill cmt retainer on dp @ 9970'. Sqzd cmtd 7" lnr thru holes @ 10,020' w/200 sx "G" cmt w/l% CFR-2. Max press 4100#. WOuid not hold. Cleared holes. CIP 3:00 p.m. 7/14/69. PO retainer. Circ & WOC 8 hrs. Stabbed into retainer @ 9970'. Sqz cmtd holes @ 10,020' w/200 sx "G" w/l% CFR-2. Max press 4500#. Final standing press 4200#. Held OK. CIP 2:00 a.m. 7/15/69. PO of retainer. Reverse ¢irc clean, recvrd trace of cmt. POH. RI with 8-1/2" bit & Csg scraper to top of lnr. Circ clean. Ran 6" bit & 7" scraper. Drld out cmt & retainers @ 9970'-10,600'. CO to 11,345'. Circ clean. Displaced mud w/salt wtr. POH. Schlumberger perfd for DST four 1/2" hpf using hyper- jet: 10712'-10728,, 10828'-10838, ~no~, 10899'_ 10902'-~na~, ~ ,.. , ~uoou -zu~/3 , 10883'-10891'. 10895'- @ 10 R~n' n_~_~ ~ _aZ W/tiOWCO drill stem tester on dry dm ' Set pkr , .... u~=ne~ coo± ~or IF. Fluid slowl · pkr, rest @ 1 ~, _~ ..... ~ _ y ~ropped zn annulus. Released 0,~ ~uove sazd nerds ~ L~ ~ ....... -~ r ~ ~,u~u . upened too± ~or 1/2 hr IF. ~-~ uxow zor 30 min. Closed tool for 1-1/2 hrs ISI. OPen tool for 8 hrs flow period, light to medium blow w/gas to surf in 5 hrs. Bl°w 'decreased entirely at end of 8 hr period. Closed tool for 8 hr FSI, reversed clean. Recovered 30 bbls oil w/9.2% cut w/l% mud, followed by 141 bbls oil w/45 5% cut w/20% mud. Oil gravity 31" dry. · Total recovery 171 bbls (full dp volumn). Estimate lost 25 bbls wtr around pkr when pkr failed on IF. Released pkr @ 8:00 a.m. 7/17/69. POH. l~rm No. STATE OF ALASKA OIL AND GAS CONSERVATION CONU~AITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. ~ELL ~,' ELL OTHER NAME OF OP]~%ATOR 3. ADDRESS OF OPEP,.AT~R 4. LOCATION OF WELL SUBMIT I~q DUPLICATE %. API NLrMEKICA_L CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIA]~, ALO'I ih~. O]~ TRIBE NAME 8. L~-~IT,F.~{ OR LEASE N.~ME 9. WP~LL NO. 10. ~'~ ~:,.r~ A-ND POOL. OR WILDCAT 11. SEC., T., R., M.. (BO~I~rOM HOLE o~ l~. PEtLMIT 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~N'GES IN HOLE SIZE, CASING AND CE~IENTING JOBS INCLUDING DEPTH SET A/XTD VOLUlVIES USED. PERFOi:[ATIONS. TESTS A_N-D RESULTS. FISHING JOB,S. JLrNK IAI HOLE A-ND SIDE-TIq~ACKED HOLE AND ANY OTHER SIGNIFICANT CHANGF. S IN HOL]~ C~DI~DITIONS. TRADING BAY UNIT STATE G-30,..JULY 1969 .(continued) IH 4813, IF1 1370, FF1 1627, ISI 4197, IF2 1673, FF2 3685, FSI 4356, FH 4813, IFlperiod - 30 min., ISI period - 1-1/2 hrs, FF period #2 - 8 hrs. FSI period - 8 hrs. RIH w/bit & scraper to 11,345'. Circ hole clean. Spotted 160 bbls protectomul invert emulsion pill 11,345'-8400' PO & 1.d. 3-1/2" dp. Schlumberger perfd four 1/2" hpf..w/4, thru csg carrier, 11299'-11264', 11216'-11179', 11130'-11078', 10914'-10902', 10899'-10895', 10891'-10883', 10875'-10860', 10838'-10828', 10728'- 10712', 9977'-9956', 9892'-9878', 9857'-9824', 9766'-9702', 9681'- 9660', 9610'- 9588', & 9563'-9537'. Ran long string & short string, 3-1/2" 9.2# N-80 buttress tbg w/special clearance couplings. Hung w/7" single Hydroset pkr @ 10,619' & 9-5/8" dual hydroset pkr @ 9423'. Landed tbg. Removed BOE & riser. Installed Cameron dual xmas tree, tstd w/5000# OK. Installed flow lines. ~hngd over from salt wtr & protectomul to diesel oil down annulus w/returns out both long & short strings. Long string immediate SI press 750#. Short string SI press 650#. Dropped ball, set pkrs. Press tstd OK. RIG RELEASED 12:00 Noon 7/20/69. 14. I hereby certify that the Ioreg~q'~n~s/~Ye a. nd co/re~ SmN~D '~'~~~ /~/~=TLE Dist. Drlg. Supt. DA~n~ 8/11/69 , ' - t D .-,,. -.Lai/xe';/) ' NOTE--Report on this for~/is ~equired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. SUBMIT ~IN DUPLI,. STATE OF ALASKA ',see other in-[_ ~.~ ,~ .~% OIL AND GAS..-CONSERVATION COMMITTEE ..... .. ,. -~ .'-, ! 50-133-20187 WEtt COMPLEY~ON OR RE¢OMPt~TION R~RY AND LOG * ............... r ~ 1 ~ - APL 187230 la, TYPE OF WELL: OZL ~ ~AS F-] C'q ~ :%. b. TYPE OF COMPLETION: . , t. :..~-. , .-,- NEW WORK .... ,,'ELL ~ ~ DEEP- O,'E. E.- E] ~'""E] o~,, BA£K' -L~J RESVR , ,~ ~2. NA~E OF OPZaATO~ }' i ~. ADDREgS OF OPERA~OR ~ ....~ . x~.,~ce~onductor 44. Leg 2,:A~76'N ~ 13:~8~ ~ SE ~orner Sect 29 T9N, R13~, SM. :~: "' ; .. ~ ~ ' ~ ~ ~oa. ~,r~a~ ~,~r~,a ~, 2965~L& 2325'E of s~rface~ocatiqD~ ~ At total dep~ -."' ; ~ 3377'S & 2414'E Of surface l~atiPn ~ :~ ~' ' ~/~/~ I ~/~/~ ~ ! ~/~o/~ ~ [ at + ~ ~ w : .,~ ~,~ "' ~ ~ /West Foreland 107~2 ~ .969~10210; T~D ~:~ CAS~G ~ (Re~ all strl~ ~t ~ CA~G SIZE .. ,Z SIZm TOP (MDj (MD) SA~S ~T*~ S~ZE ,.~:, . D~:~ (~) .... 8. UNIT,FARM OR LEASE NAMe: TradinE. Bay lJn~t o. w~ ~ro. :. Sta~e :o~3q (11~3) :o. r~ ~ ~. o~ W~, , ~CA' '--' " ' Mid ~nai r~nur ~ver~ Fo~land n. ~., ~., a:; ~.. (~ aox:: Sec. 3'3,~. ~9N, ~3W, :SM. PERFORATIONS OPEN TO (Interval. size and !four 1/2" hpf ': 99 "' :' I10712-1072~ ~ .~10828-10838 ~'l ? 8_11:i~30 '::;.,-: .:u .......... :... i .... ... ~~._ .., PRODUCTION , DATE FIRST PRODUCTION METHOD (Flowh~g, gas li~t, type ofJ, ptlmp) !7/21/69 ' } ;: ~, ,....~ v~Tz o~ ~zs~. SIZE .~7/21/69 4 95/64 ~s'r ~mo~ .::60 ', FLOW ~BING ~~~ O~BBL. "" ~ 110 250 ~ ~ 2577 DISPOSITION OF GAS (~Old, i lei vented, etc.) WATER---BBL. OIL GRAVITY-API 159 TEST WITNESSE] S~ZS, "i 33. I herdb~ certif~ SIGNED INSTRUCTIONS . General: This form..is designed for submitting a complete and correct well comple~ic, n report and log on all types of lands and leases', in Alaska.' .... .. .. Item: 16: Indicate which elevatibn is used' as~-r'eference (where not otherwise shown) for depth measure-' mentsi::~iven· in cther spaces on this form and in any attachments. - ._ Items 20, and 22:: If this well is completed:ifor separate production from 'more than one interval zone (multiple completion),-so state in item 20,'"'an-d in item 22 show the prcducing interval, or.. intervals, 'top(s), bottom(s) and name (s) (if any) for ~nly tl2.e j,q.~t_er..val reported in item 30 Submit a separate report !page) on this form, adequately ~identified, for each adclilional interval to be seperately produced, show- ing the additional:-dat~ perline.n.._t to such interval. It®m26: "Sacks Ceme'nt": Attached supplemental records for this well shouid show the details of any mul- tiple stage cementing.and the location ofi't.,h,Y:'cementing tool. ' · !.t. em 28: Submit a separate completion re,-.~.~.rt on this form for each interval to be separately produc~. (See instruction for items 20 and,' 22 abov,e):" " ~ ~ , yJ. 34. k'~viA.llY O1~' Im'O.R.MATION TF.,ST~ INCLUDIN(; INTERV~ ~D, P~U~'D~TA ~ ~OV~ OF OIL, · , - :~ 35,. O~Ol~ MARK~ , ~ ' ..... ~.- :j. WA] AND ~MUD . . '" ~' { ~ ' ' ' ' '~ ~ ':' i':' . N~ q"' ,DS~ ~1' 10:712 - 1'0~9iJ4'' -Pkr 0 10616. Tail ~ 10029. 'Light blow Pf gas to ... '-. .- "~ ~' '~ i. surface in '5 hrs. Dead'"'in 7_ hrs. Rev.ersed 'out -~- " "~ / 30 bbls cut 9.g% ~/iZ mud a 31 dry gra~Sty, Middl-e [enai i'A" ~ ' . : .... ~ . ~ ' 234~ 2338 ' ;r~ .... ~ : ~ 1~1 bbls ~5 5Z'cur 0/20% mud ~ 3~ dry, ~ravity ..... "B" 3329 32~9 · ': ~ "~ ~' ' : ~' ' "C" 4110 3914 r ,... ¥ , : ~ .~ ·. " .. .. ;:. :.~ (.; · ,-~ .IliP 4813 ',' . IFp 1673 .... '-"'I)" 4492 '4240 '; :~ ' t .... t i , ' ' ' ' · , .~; .:~ 'IFP~ 1370 FFP 3685 .... "C" 9209 8362 ~ ~< ,,~ ' ':' :FFPI:.]..62'7' ' . -F.CIP -4356 tiemlock 10053 9117 -~.-, ..... ..: . ".~;" :: · ..... · i, CI:P -4197 FHP .48:1:3 West For~~]and, . 10627 96~2 .. ~¢P: - , , . ..... ..... · . a '. ~.. . . ..........'~.~ .r> .... _ ~'~ ~ ." ".. ', . · :. ' ' ' '~i'"J,'-'..-; ~ ~,: ............. 7:' ..: .... .- . ' ' :' ' ,,.' *- '' : ' <1 ' ' ' - ' -:...f ~d. CORE :DATA,. A3~ACII BRI{P D~CRIPI~ONS OF LITHOLOGY. POROSI~'~. FIIAC~R~.7 APP~NT DIPS " L 2;'1 - . ............. - . . . , , , .~'-_f . ':. r , , . ,-C . ..f AND ~:D~PEC~'EI) SHOWS O~ OIL, G~ OR.'WA~.. '. · . il r ii i i ' ' c .' ') : . ' ~: · · , { ~. .- . .:::... :-.. . ._ .... . . ..{ . .,,j . ..~ . ~ ; . ...'~. ~ :: :: ....:. ., .... . .,~ , · . · ~O~;a :' . . .~ . . . ..- - . j · ;. . ,?~ . . . . -. ~ ,.' ~ .... -. . , , -- .~. .. ., . .. .. .. .... - . . ... , .~ : ..... ~ ' . , l... ~ ~ ' .... ,~ - . .~': .... r .... ~- ~ ' "'~ r"-'. . Form P--7 SUBMIT IN DUPL: ~T~'['1~ OF ~[,~K~ (Seeoth~r tn-[ , WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ............... - ~L 187230 b. TYPE OF COMPLETION: n~CX '~ ". n~sv~, Other EN ~VELL OVER . ~. NIME 0F 0P[RiTOR .Union O~.!. Co~pa~ny of California ...... 507 ~. Northern Lights Blvd., An~horhge, Ak. 99503 4. LOCATION OF WELL (Report location clearl~ and in accordance wttk~any Btgte requirements)* ~,,~c~onductor ~6, Leg 2, 1376'N ~ 1378~ from SE corner Section 29~ TgN, R13~ SH. ~ top pro~. interval ~po,t,~ b~low 2350~S ~ 2113'E of surface location tt total ~p~ 13. DA.TE SP'UDD~ '5/24/69 18: TOTAL DHPTH, .MD & TVD ~9. pLUG ~CX MD a ~n~, ~ ~LTmLE ~L., [ ~1. 11451-10328 '/ D~ 11345-10250 / ~w~w' ' ~ 'l ,o,,,,0,oo~s_TD ~.,PRODU~NG ~VAL(S), OF ~IS ~M~TIO~, BOOM N~E (~ A~'~)*' .Middle Kenai "G" :9537-9977}~ 8650-9048 TVD tIF INDIA_N, AJ.J_O~ ------- UmT,F,~,M OR Trading Bay Unit 9. WI~L NO. State G-30 (11-33) 10. Fr~.r~ AlhrD POOL. OR WMi~tenai "G" McArthur River-West Foreland n. s~c., ?., R., M., (mYr~OM aorta OBJECTIVe.) Sect.-33, T9N, R13W, SM. 3377'S & 2414'E of surface lodation ~.~m~,.~o. 69-47 DATE T.D. ~CHED {15. DATE CO,1U_P,$US~(IR ABA_ND, [le. EIb, A~ONS (DF, RKB, RT, GR, .ETC)' 17. EIb. CASlNGHEAD 7/8/6'9 ! I 7/20/69 IR.T. 99' ABV MSL 59' ABV MSL INTERVALS DRILLED BY ~r CABLE TOOLS 23. 'WAS DiR~ONAL / yes 24.. TYPE ~L~ECTRIC AND OTH. IilR !DIL, FDC-GR, BHC~$on~, ItRD '~. CASING SIZE 'i7-3]'~" 1! ! ! 13-3/8 19-5/8" , ............ ~i!,~ ........ ~'~ I ' i CASING P~CORD (Report all strings set in well) . .... · ~' ~l' ' ,! 11I j ~,, ' ,! iiii i ii '/.312 ~all,';s~iral ~d 5~0 ' " 0 ~1 ' "G" [ ~ , l'~$ sxCass "' ' ' 00 ' + 0 " " / 6i f: " /J-ssi I , ,'X, Cl ' , . ~'"'~'. / . , . , , 26. LINER P, II c O,P,D ~" [ 979f ;.;['11444 [ 1000 sx. ' I ' " [ I 28.: ~E~O~TIO~S OPeN TO P~O~O~ (lmerval. size ~d number) ~Four. 1/2" ~,hpf }9537-9563 '~ 9878-9892 ~: 9588-9610 9956-9977 . , ~DATE FIRST PRODUC~ON [ ~OD~CTION ME'IHO'D (Flowh~g, gaa lift, pump~size and type of p~p) 7/21/69 ~ .Flowing ;7/21/69 [ 4 ' ':1 90/64 . . FLOW ~BING' ~G P~S~ [CA~~ OI~BBL. G~~. ~. I ~ [~-~ouR ~ zso I 250 I i 1913 I 1148 31. VXSPOS~TION O~ ~S (Sold, ~se~ ~ ]~el, vented, etc.) I ~'?'" TUBING RECOP. D :. SC~ (Mill) [ SIZE [' DEPTH:SET (MD) [ P*CII~ S~ (~) ' :~ 3~1~ , 9~3.., . 1942'3 ',.'(top} AC~D, SHOT, ~'~, c~ SQUE~ZE, , 10650 [2-cmt sqzs 400 sx ':'G" 1% CFR-2 10020 [2~.cmt sqzs ~o0 WELL STATUS (Pro~.ucin~...or shut-in) ', " Shut WA~BB~. [ GAS-OUu p~TIQ 191 ] 39.'50' . ' 600 ''-~ WA~BtlL. ]OIL GRAVITY-AP~ I 237 I 31'0° WXTNESSED ' ~ t"~ '.. ~ LIST ATTACHMENTS ~3.1 hereb'~ certify ~4/the to.r~:0i~ and attached'information 1, complete and eorrebt aB determined from ,~[/U/ / -Lb~.. "l'alie~: ' . -. .' · . . . (See/Instructions and S~c,s ~or Additional Data on Reverse.Side) INSTRUCTIONS .~; - General: This form is designed for submitting a complete and correct well completion report end log on all-types of lands and .leases in Alaska. " cltem:-'16: Indicate which elevalion is used as reference (where not otherwise shown) for depth measure-' merits given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate- production from more than one interval zone (multiple completionL so state in item 20,'an'd in item 22 show the prc. Jucing interval, or: intervals, top(s), bottom(s) and name (s) (if any) for .0nly the interval reported in item 30. Submit a separate report ..(page) on this form, adequately, identified, fOr each ad6itionsI inte~ val to be sepera.tely produced, show- ing the additional data pertinent to such interval. : Item96: "Sacks Cement'".: Attached supplemental. records for this well shoukJ show the details.of any mul- tiple stage cementing and the location of the' cementing tool. ~ . .. .Item 28: Submit a separate comPletioa report' 0~ this form for each interval to be separately produc~. (See instruction for items 20 and 22 ~bov.e).- ,, 7' 34. S~MA.R¥ O1~ F.O~,~4%/[ATION TESTS INCLUDIN(] INTER~kL ~D, P~U~ DATA]~ ~OV~'OF OIL. 35. G~GIC MARK~ :') ' WA~ AND. MUD" : , . MEAS. . . [ ;. .' ' NONE H~ddle Kenai "A" 23~0 2338 :' :'~' " ~ "B" 3329 3249 ' ~ ..... ~'"C" 4110 3914 ' ' ..... "'D" 4~92 ~2~0 ~ ~.'~ ~'F'~ 7758 7112 · . ~: " "C" 920q 8362 .... , ""> ,~O. rCO~E,DATA. A~ACII BRIEF D~CRIPI~ONS OF LITHOLOGY POfiOSITY. FR~C~R~,. APP~NT DIPS ~ · , . AND~.D~EC~'EI) SHOWS OF OIL, G~ .. . . .. ,. ...... . .i r''. .-. . , ...~ . .' '. NONE : .. ~.. - : . ~ .. . ., -, . _ .~ ~ ... · .~ .' . ' .~ '~ . :-.. · . · . . - -~ ' ' . L . , . ....- . ~ .~ . ~ ,, REPORT and PLAN of SUB-SURFACE SURVEY UNION OIL COMPANY ~B.U. (~-30 COOK INLE~ ALASKA ,rOB NO.. DATE ,JULY I969 DRILLING CONTROL CORPORATION LONG BEACH, CALIFORNIA ! . i .... i. ,, , , ·, , . . fSUB, VEY DATA SHEET COMPANY, L Union Oil ~y ..... DATE July 1969 . JOB NO. . , · Alaska WfLL T.B.U. G-30' FIfLD ., COUNTY STATI ~ . - MEASURED DRFFF TRUE DEVlA~N DR~T RECTANG~R GOORD~qATES DEPTH ANGLE VERTICAL COUBSE D~N ' REMARKS "500 0° '~0' '500 00 ' N 51 E ' 21 ~1 58· ~ ' 630 0° 25' 630 00' N 32 E .1 04 2 08 849 0° 10, 849 00 S 65 E 77 2 66 1163 0° 20' 1163 00 S t3E 1 01 3 07 Gyro .... 1477 0° 25' 1477 00 S 07 E 3 28 3 34 -- survey · 1980 0° 45' 1979 95 6 58 N 83 ~: 2 48 9 87 2055 2° 15' , 2054 89 2 94 N 85 E 2 22 12 80 · 2118 3° 45' 2117 76 4 12 S 83 E '~ 2 72 16 89 2149 4° 30' 2148 66 '~ 2 ~'43 ~S ~7 E 3 27 19 26 2212 5° 30' 2211 37 6 04' S 60E 6 29 24 49 2362 7° 15' 2360 17 18 93 S 47'E 19 20 38 33 2519 13° 00, 2513 15 35 32 S 41 E 45 86 61 50 2560 14° 30' 2552 84 10 27 ~ S 48.E 52 73 69 13 2622 15° 45' 2612-~51 16 83 S 59 E 61 42 83 56 2800 19~ 00' 2780 81 57 95 S 65%E 85 91 136 08 2923 23° 15' 2893 82 48 56 S 64 E ~ ' 107 20 ·179 73 3016 26~ 15' 2977 23 41 13 S 63 E 125 87 216 38 3207 29° 45' 3143 06 94 78 S 63 ~,.. ' ' 168 90 300 83 3336 30~ 15' 3254 50 64 )9 S 63 E 198' 40 '358 74 3494 31° 30' 3389 22 ~ 82 56 S 62 ~ 237 16 431 64 ~ . ~ 3619 32° 00' '3495 23 66 24 · S 62 ~ 268 26 490 13 3806 31° 45' 3654 25 98 ~40 S 60 E 317 46 575 35 3884 31~ 30' 3720 76 40 76 S~6~ .. 337 84 610 65 4198 31~ 15' 3989 20 162 89 S 62 E 414 31' 754 47 4418 31~ 15' 4177 28 1t~ 13 S 61 E 469 64 854 29 . · ., .~ .~ - .. ,. DRILLING CONTROL CORP. eH~T NO. 2. , ~U~VEY DATA BH'EET COMPANY Union Oil Ccr~any OATE . July 1969 Joe No. wEc~ T.B.U. G-30 FIELD, . COUNTY. . STATE Alaska , TRUE DEVIATION DRIFT RECTANGULAR COORDINATF_~ MEASURED DRIFT VERTICAL COUBSE D~N KEMARKS DEPTH ANGLE DEPTH , NORTH SOUTH EAST WEST 4647 31° 30' 4372 53 119 65 S 60 E 529 47 957 91 4813 30° 15' 4515 93 83 63 S 57 E · 573 38 1028 71 5043 32° 15' 4710 45' 122 73 S 55 E 643 78 1129 24 5219 32° 00' 4859 71 93 27 S 54 E. 698 60 1204 70 5260 31° 00' 4894 85 21 [2 S 52 E 711 60 1221 34 5 5405 29° 15' 5021 36 70 85 S 44 E 762 57 1270 56 5627 30° 00' 5213 62 111 00 S 44 E 842 42 1347 67 5845 30° 30' 5401 46 110 64 S.44 E 922 01 1424 53 6033 28° 45, 5566 29 90 43. . S'34 E 996 98 1475 10 6178 27° 15' 5703 20 70 51 S 33 E 1056 11 1513 50 · · 6477 26° 15' 5963 29 ·128 26 S 31 E 1166 05 1579 56 6725 26° 15~ 6185 71 109 69 S 30 E 1261 04 1634 41 6917 26° 15' 6357 91 84 )2 S 29 E 1335 31 1675 58 7244 24° 30' 6655 47 135 ~0 S 27 E 1456 13 1737 14 ' 7431 24.0 30' 6825 63 77 55 S 26 E 1525 83 1771 14 /' 7691'- 28° 15" 7054 ~6 123 )6 S 24~E 1638 25 1821 19' 7885 32° 00' 7219 ~8 102 ~0- S 21 E 1734 22 1858 03 8077 34° 00' 7378 36 107 36 S 23 E .1833 04 1899 98 8361' 32° 15' 7618 55 151 55 S 22 E 1973 55 1956 75 8562 ~!° 00' 7790 84 113 52 S 22 E 2069 53 1995 53 9076 28° 15' 8243 62 243 29 S 23 E 2293 48 2090 59 9260 27° 15' 8407 20 84 25 S 22 E 2371 59 2122 15 9435 26° 15' 8564 15 77 40 S 21 E 2443 85 2149 89 9615 27° 00' 8724 53 81 72 S 20 E 2520 64 2177 84 9771 26° 30, 8864 14 69 61 S 19 E 2586 46 2200 50 , · , , ,,1 , .... . ~ __ * . . ;. - . , DRILLING CONTROL CORP. 8,EET NO. 3 . . BITItV~Y DATA SHEET OOMPANW , ~nion Oil ~~y ..... OaTe July 1969 ....... WELL T.B.U.. . G-30 FIELD, .. ...... COUNTY , STATE ~aska ~ D~A~ON D~ ~T~G~R C~~A~ ~UR~ DB~ VER~CA~ CO~E D~ON ......... D~ ANG~ DE~ NO~ SO~ ~ST ~T 9909 26~ 30, 8987 64 61 58 S 18 E 2645 03 2219 53 10090 26° 15' 9149 97 80 ~5 S 18 E 2721 16 2244 27 10237 27~ 30' 9280 36 67 88 S 19 E 2785 34 2266 37 10547 29° 00' 9551 49 150 29 S 18 E 2928 27 2312 81 10680 29~ 00, 9667 81 64 48 S 18 E 2989 59 2332 74 10778 29° 15' 9753 31 47 98 S 17 E 3035 38 2346 74 11044 300 45} 9981 91 136 30 S 13 E 3167 89 ~377 23 11450 31° 30, 10328 05 212 ~4 S 10 E 3376 81 2414 17 . ~S~ 4150 )1 S 35° 34' E . , ( , . , , ,, ~ ~ ~ i . ~ ~ ~ ,, ~ ,, , .... ~ ~ ~ , .... -- ,,,~ TY~' OF SUrVeY' G.Y~¢X~COPIC ~...~LTTSH T/J ,;', ' ~,_o. ,, · DEPTH: FRO~-- - LEASE:- TraDiNG BA'Y UNiT T~UYDING B~Y FIELD:_._ IRADING BAY G,30 ...... ?.i:-.-"-i'-;~':.-' :..,-' .-.: ."-.'... -.. "i.-:.'.~-~_~;'..~;;:'-;::~'i?'C:~:: ' MAY 27-31 1969 SURVEY DATE _~.IRAD_.ING,__B. AY~-..' ~.'....-:...:...i ...... ~' ~'-:: .... '.' '.'- r .- '~.." -" · '" .']':_._:]]_],~--':..~ "~'. ............. " V.ER.IICAL ..... SEC,TION._COJi4PUT.ED_.ALON~' ~ CLO. SURE ................. ..... . "DEPTH '."-'":::;.'"DEPTH ".:.il DEG M[N 'DEG '- '- DEG/iO0 SECTION .'"NORTH SOUTH EAST WEST .:'"'200. 199.99 0 30 S 28 E 0.50 0.48 ' -0.54 0.14 .... ~ :"---'-':-' '-"~,i.'~::~:'.:::i:-"' ..... ;:' :' ...."'..i".' .... -"-'. . . . .. ...., ~- '. .. ' , ._-., .... .~ -.'~_.-~ __ . . : . . '- .... 250','":'i:""'2~9,99 0 20 S 48 E 0 43 0 77 -0 73 0'36 --. ' .--. - . ~1 ~ .. . · -3_QO ..... ::_ 299.._9_9,__::.~:~..:_.-0_._30 .... S'_6 5,_'F" .... 0_. ~ 1'_ ", ...... :_:l.. 18 ......... '__ - .... : ...... :0.. 9 2..: .......... O. :76 ............... : ............ .-' .~' .350....'::. 349,99 :....- . ,. 0 20' , N 48 E. .- ' 0.96 1,20-. ':-: . -0.72 0.97 ,.'::-~·.---': :.~ ~.-<:r-<:"ii~ii:!~:i ::.?:'<:%:-';.:i?.:::~"'.:...~:'~:~:~:'::~"??!-i:~-~?:..~',:.;:?: .-:. ...... ~.· .:,':?.--i·:~.~.'::'.-' :-·~: .. -- ,::::" :',." .. ,-...::.-:...?.:::--:-.":·._':. "::..i'. ...... -.¥ YiLi!':rrl-r? ::' .:;L ::i. '.. ........... .26 .36 .59 .." 1163.". ..... '1162.97..':.'..:.:~:'.:::"!-'~:-:':, 0'20 ,.:":'- '-' S 13 E "' "' 0.08'~:;'. '.: 2.'91 -1.01 3,08 . ". 1477.' .... 1476.97 -" 0 25 -' ' 'S 7 'E ..... '0'02 "':'-' "' 4.69" !":'" ....... .... '¥: -3.27 3,36 "- '-"-'- ........ :-..:.~-.!:iL"??~?':?.-'.,:::~:.:'.:-.,':-..~ 4-'.:-.'.~.:~ '.:-~.'-'~-:.~".~:' "~:-'."-'--'-" ' '" ':'-' '" ' '~ -.-' ':-:.~'i :- .":- :<':.::"" ': .:. '"-'~.. :. ' ".' .... ~' ":'~-':",' ' "' -'- ' .... -: -: **~* THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THE TANGENTIAL OR CHORD METHOD *~* ".: -'~i'-~'~!:'::~: -?:'-:_.:: ii.ii::'~:.! :.:':.:.?:._,. ¥ ~,'. :. :.. :.......~ _,-~.. ...... :, ....:: :'.'...:'.... .. ; ' . .- ...........: ~.~ .:..:.:: :~...~ :'.~.:~ ......- - . .~"' . . . ... .'-,'- -:: i-.--._:..:-·.''. HORIZONTAL DISPLACEMENT': ~.69 FEET AT SOUTH'- 45 DEG. 41 MIN, EAST(TF~UE) . . ' ,...-.....:::.:.:.-.',.::..;..,, . - ... , -'.'...~-._ -.. . , , .-.. '..:: . ........ . .....:::, .':.' .... .' .'.' .... . . _ ., . . ..- . :-- .. :': :.....- .-.. :.!..... :._... ,......:. ::. -..... :......... _-.-... i. ' 'i' '"' '"::":::':;:.,:::'"':':~;::.:":'.; "!":~.' :'!-'!:,"-': :..:~' :. ':.i'i :-'~.' :'. :':":-. ~ i:': - :' .... -.:: "'-.-'.' ~:':' :: ::'":i:?::-:':-.:::~i:';;?i!: :.: ~.?-'-'---~:.'-:)-'.:'.: .):':' :.---:" '-"" ::. -".-. "- TRANSN;ITTtNG T~E FOLLO~.'VlNG: ,::!.? P.O. BOX ~.1~.? · ANCl,-IORAG~'. ALASKA · TRANSMITTAL STATE OF AIAS}~ Division of Oil & Gas ~mchorage, Alaska Attn: Mr. I-[arz~y Kugler Dear Sir: i We have transmitted this date v~a Personal ~$1iver~ ~ _'..'.lashed ,7: Core ; . samples from the: '~ ; Mobil Oil Corp. - ~C No. I-1 9 Boxes - ~'.~ashed 11,700-1~,71~ Core No. l, ~ 3, h & ~ Colorado Oil & Gas Co. - Shaviovik No. 1 8 Box~,s - Washed 1170-7990 Core No. I & 2 ¢O~A~V July 22. 1969 _ Hill ~-oductions Co. - No~ 1 Fishhook 1 Box - l~ashed hO-23ho Please acknowledge receipt by returntnE one copy of this transmittal. Very truly yours, American Stratigraphi¢ RGB; JP Receipt acknowled ged Remarks: ~ .-~/ Packer r~tallation Record ,ox ,,o,. ~,~,,. ,~x,,,,, Tubing Uetail Re rt Prepared F'or ..... Co~npany ....... Date " ~- ' 7' ZO- Lea~e .... Well No.: [,Field .... , ...... I 'Co. or Parish . ' ..... State ~ ~ New Completion ' ' ~ ~ Workover , , , [Size Weight '* Grade' Thread Depth ...... CASING . Size .... Weight ' G;~de Thread Depth LINER TYPE OF TUBING FOR STRING NO. ' I Size ' ' I' Weight ' I°'~ae' ' 'l Thread I De'pth "' t ~f ' /~ ' , ......... , ,, ~ ,, ~ ~ ..... ......... , ,, ~'o- ~ ~:~o~' ~Z/c~/ ~.,~ZL zzu~ ..... . ' . ~ ....... .~ .......... ,, ~,/~-~. ................... FM Union Oil Comoan~ .~. California 2805 Denali Street, Anchorage, Alaska 99503 Teie,shone (907) 277-i481 june 9, 1969 HLB~ TRM ~ OKG KLV --------- HWK ~' REL -------'--- WEST FORELJuND AREA State of Alaska ADL 18730, WFore-S Direc'tor Division of Lands 306 West Fifth Avenue Anchorage, Alaska 99S01 Dear Sir' In accordance with the provisions of the captioned oil and gas !ease~ Trading Bay Unit G-30~ drilling from the Grayling Platform located on State Lease ADL 17S94 was spudded on May 24, 1969. The proposed bottom hole location of said well is approximately 1,360' South and 1,300' East from NW corner of Section SS, TgN, RtS W, S.M., on said captioned lease. Very truly yours, Robert T. Anderson District Land Manager - Wade %% McAlis~tef STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPEP~TOR Union 0il Company of California 3. ADDR~S OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. I&)CATION OF WFJ-J.. Conductor #44, Leg #2, 1876'N & 1378'W from SE corner Section 29, T9N, R13W, SM. '5. AP1 NUS~ERICAL CODE OKG _ 50-133-20187 K V_ ADL 187230 ,,,,m ?. IF INDIA]~, ALOTI~ OR TRIBE 8. L~IT,F.~{ OR LEASE N.~E Trading Bay Unit 9. W~L NO. State G-30 (11-33) 10. Fl~i.~ AND POOL. OR WILDCAT West Foreland McArthur River-u~AA1. w~.o~ "~" ll. SEC.,T.,R.,M..(BO~'T~f~L~ OBJECt fYi) Sect. 33, T9N, R13W, SM. 1~. PEPdVIIT 1~O. 69-47 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~qGES IN HOLE SIZE, CASING AND C]~i~IF_2NTiNG JOBS INCLUDING DEPTH SET ~ VOLUAgE~ USED, PERFOP~ATIONS, T~STS A_N-D RESULTS, FISHING JOBS, JLrfqK I2q HOLE A_ND SIDE-/-fLACKED HOLE AND A_NY OTHER SIGNIFICANT ~GES IN HOLI~ CONDITIONS. TRADING BAY UNIT STATE G-30 (11-33), J.UNE .196~9 Drld & DDrld 12-1/4" hole 1980'-4813'. Opened 12-1/4" hole to 17" fm'0-4813'. Ran 124 its 13-3/8" 61# J-55 seal lock csg. Hung w/shoe @ 4779'. Cmtd w/2000 sx Class "G" cmt with 1/2 cu.ft, perlite / sk. followed by 200 sx "G" w/2% CdC12. CIP 1:30 am 6/8/69. Good returns to surface. WOC. Cut off csg. Rig ~elease~@ 6.a~. 6/8/69, moved to G-18 repair. Moved back 12 midnight 6;/8/69. Installed csg head & BOP's, tstd OK. RIH & drld collar @ 4735'. Tstd pipe rams OK. Drld 12-1/4" hole to 10680'. Circ & condition hole for logs. Ran Schlum DIL~log, density log &.sonic log. Drld 12-1/4" hole to 10700'. Circ for csg. Now rng 9-5/8" csg. :t I hereby eerti£y ~~/e ,ore~.o'~j~Ja~je ancl eorrec~¢¢ NOT~R~port o~ this for~Jis required for each calendar month, regardless of the status of operations, and must ~ filed in duplicate with the Division of Mines & ~erals by the 15th of the succeeding month, unless othe~ise directed. UNION OIL CO. OF CALIFOR,qlA DRILLING RECORD' SHEET A PAGE NO., Trading..Bay Unit State%VELL NO.' G-30 SPUD DATE 5/24/69 LEASE . Ii. I' ~OD E C 0 FIELD McAr thur River - CONTRACTOR ~ TYPE uNIT .National 132~. LOCATION · Leg 2,i Conductor 44, Surface Location DRILL 'PIPE DESCRIPTION 1876'N & 1378'W from SE corne~.Section 29 T9N~ R!.3W, SM. ' . PERMIT NO. 69-47 'SERIAL NO/kDL 187230 T.D. 11451 ' T.V.D. 10328 ' DEVIATION (B.H.L.) 3377'S~ 2414'E of surf loc COMPANY ENGINEER COMP. DATE ELEVATIONS: WATER DEPTH M.T. TO. OCEAN FLOOR R.T. TO MLLW R.T. TO DFJLL DECK_ R.T. TO PROD' APPROVED: 7/20/69 RIG NO. 235.60 , 110.~0 19.. 30 54 BIT RECORD .... S4,UD VEL. DEPTH & DEVIATION BIT ' , DATE. DEPTH NO. SIZE MAKE TYPE I-' JET DEPTH VERTICAL SIZE OUT FEET HOURS ANN. JET DIRECTIO}IAL 5/24/69 1RR 15" HTC OSC '530 195. 4 , 25 ' H01 I~ 2¢' ! Servco Exp. · 530 26 " ' ,, ,, " 53o 30" 1858 3 " Globe ST3G 1/4 1980 122 3-1/2. " 433 T-.~ .B-1 31 1980 4i " Reed YTIAG 24 2257 277 9 .. DDrld T-7 ~/1/69 22.57 3RR ',, Globe ST3G 14 255]. 294 2 121 433 I ' 2251~ 5 " '.- '~Reed YT1AG 24 2693 ,1.47 3-1/2 DDrld T-4 B-.2 i 2698 3RR.~ " Globe ST3G 14 3079 381 5-1/2 110 398 T-6 B-4 .... 2 3079 6 " " " " 38~4 8O5 ]2-1/2 " '" T-7 ~-3 2 3884 7 " Re. ed YTIAG " ~4]..S 534 8-1/2 " !' T=5 ~-~ 3 4418 8 " Smith DC}[ ". 4647 229 5 " " T-6 ~-40c, 1/4 3 4647 9 " Reed YI1AG " I 4513 ].66 ' 4 I 4813 hO3 17" Smith" 6 point 2711 2181 19-1/2 78 T-6 ~-3 ~ 5i 2131 ~i04 ,' . ." " 3466 755 16-1/2 " .T-5 ~ (locked) · '6 3466 !HO5 "- " '; 4334 868 1.5 " T-5 ~'~-5 .... 7 4334 HO6 " "' " 4813 479 9-1/2 " T-7 ~-5 9 4313 10 12-'1/4" ~iIC ODG 3/15 5219 ~06 " 101 325 10 5219 11 " Reed ST1AG 3/24 5305 86 4' 101 321 DDrld ' 10 5305 12 " Globe ST3G 3/15 5845 540 11 " " 11 5845 13 " Reed ST1AG 3/24 5927 82 9 83 _ DDrld 12 5927 14 " Globe ST3G .3/15 6187 260' 10 98 305 , , ~' 13 '.. 6187 15 " · Smith DGH -" 6477 290 9 " " . 13 6477 16 ,, ,, ,, i, 6725 248 8 " " I&. 6725 17 " Reed YTiAG " 6917 192 5 !00 352 . I'14 6917 1S'.'" Globe IST3G · 3/14 7244 329 12 "." ~ 15 ' 7244 i9 " Reed. YT1AG ' 7431 1~7 7 105 372 T-5 B-5 /_8" 16" 7431 '20 ". Globe ST3G " 7511 80 5. " " T-4 B-2 1 OG 16 7511 21 " Smith. DGH '; 7691 180 10-1/2 " ~' T-2 B-5 · ' 17 7691 22 " " ,'. " 7885 194 8-1/2 " " T-7 B-4 '1/8i'i' OG ..... 17 · I' 7691 23 " Reed YT1AG " 7952 67 4-1/2 ".- " T-5 B-5 1/8" OG. I'i8 i 7952'24 " Globe ST3 " ' 8077 12'5 6-1/2 " " T-4 B-1 "i8 f 11-3/4" Globe [asker = Fished! for Grant Roller & Pin ' I18 25 12-1/4" Smith OGHJ .3/14 8124 47 3 105 372 T-4 B-2 Ran on junk. i8 8163 -.06 " Cl~be I >~[T36 " 39 2 " " ' 19 26 " I " " - " 8-361 237 Ll-1/2 " " T-8 B-8 1/8" OG · '' 19 8528 27 "" " l" " 1!6~ 9 " " 20 27 " " - " " 8562 201 11-1/2 " '" 'T-4 B-7 '~ 20' 8921 28 " " ST36 " 8921 359 12"1/2 " " ~-7 "B-8 1/8!' 0G ' 21 . 29 " Reed · YT1AG " 9076 155 9-1/2 "'1' ' ' T-- 8 B--3 ' I2t 9204 30' '" Siobe ST36 " 128 7. ,, ,, "'22 · 30 "'" " " ~ ' ' I 92~0 184 10-1/2 " ." T-6 B-6 1/8" OG " " 9435 175' i1-1/~ '" " T-5 B-3 22 9435 31 " " .1 ' '- -- · 23 32' '" · " ~iT36 " 9615 180 11 " " T07 B-7 1/8" 0C 23 .' .9688 33 " " ST3'6 ' 'F, - 7~ 4-1/2 " I' ' 24- 33 " ,., ',, .,, 9771. 156 10-1/2 " ,, i_7 BL5 i/8" OG -24 ~ 9909 '34 " Sm.ith Kg,~;J " ' 9909 138 8-1/2 " ." T-7 B-4 25 35 " " " i " L0090. 181 8 " " T'7 B-6 , 25 ~10i59 36" ,, HTC <DR ',, 6~9 8 . ~,, 26 36 " " " " ' ' " L0185 95 13 " " T26 B-5 26 - t:37 " Reed · SS1GJ'" i, 'i0237 ~2 4 " " T-4 B-1 " 26_ 10284 t 38 " · [iTC X55R :' 47 4 ". " 27 10529 38 ,,. ,,.. i, ,, 29'2 , 29 10547' 39'" " {lmith~ I I ' ' 1{j; ~ ' ' 8-'' I 81 '6 '! " Y-7 g-3 UNiOI, OIL CO. OF CALIFOK,qlA DRILLING RECORD LEASE Trading Bay Unit State ~VELL NO. G-30 FIELD' McAr thur. River . LOCATION ~ · .-. PERMIT NO. 'SERIAL NO .... T.D. T.V.D. DEVIATION (B.H.L.) COMPANY ENGINEER SHEET A PAGE NO. SPUD DATE ·COMP. DATE CONTRACTOR ,.. . TYPE UNIT DRILL PIPE DESCRIPTION ELEVATIONS: WATER DEPTH tL T. TO OCEAN FLOOR IL T. TO MLLW IL T. TO DRILL DECK IR. T. TO PIRODUCTION DECK APPROVED: RIG NO.., ~ - , BIT RECORD MuD VEL. DEPTH & DEVIATION BIT JET DEPTH VERTICAL E] DATE D,,EPTH N,,O. SIZE .... MAKE TYp.E, SIZZ OUT FEET HOURS A}I]~L JET ,,, , DIRECT~I.O..t{AL E] ,. 6/30/69 10680'~0RR 12-1/4" !Smith K2H . ·3/14 10700 20 1-1/2 105 372 T-4 B-4 - 3 107'78 "~2 '" ~C X-55R 3/10 10894 116' 9 125 2~9' T-4 B-8 Lost b.earin~s 6 i!1172,.~ 47 " -- HTC X55R " 11262, 90 8'-1/2 " 290 T-8 B-8 12 48R[ "' " " ' open 9791 - - 120 CO cmt . ....... ......... , , . . ...... . UNIO, I~ Oil CO. OF CALIFORNIA MUD RECORD WELL.NO' G-30 FIELD i McArthur River' DISTRIBUTOR SHEET B i~AGE NO 3 o _. ~ . DEPT~ ·WEIGHT VlSC. ' W. ~. pH SALT. OIL SA~D SOLIDS REMARKS 5/29Z6~ 600 77 49 6.2 ~.9.5 14000 6 2 15 31''l 1970 78 'iI,4S 6.4 .9.8 140100 4'i,' ~F1/2 14' ' ...... ,. ~.611,!~9, "2~9~' ,78',, ,,56., ,,6.6, , 10 134002 3. '15"' .. .. ' -2 -.i- .3000 79 43 ,. 7.0' 9..6~:13000 . IR 2-1/2 16 ..... ~ ..... · 3 4315' 79 53 7 5 9 5 12600. TR"' 3 15 · ,' , .... · ,, · .... · 4 .~ 4813 78.5 56 7.8 9.8 1200O T'R"2-1/2 '14 5 4813 78 -46 5'6 '.9.6 1250'0 TR 2' 14 Openihg hoi% .... · ._.6 ::'~. 4813'... 78' 5'~ '5"~8 9.6 12000 IR 2-1/: i'4 ,, ,,. , 7 . · 4813 ' 75' ' 51 6~0' 9.-8 12006 3-' 3 14 " .... " ' ......... , , , ,, . 8 ....~813 ..... 78 44 6.4- 9 12000· 2 3-1/2' 16 " '" i'.9 ~. 5090 74 .., 48.. 5.2 !1- 12000 ".3 3 12 "' ~ -11 5520 74 47 4.8 13 12000 4-1/2 1~1/: 13 . 7. 12'- ...... 590'~. 75 ',,48 ...... 4.6 ~0 ~i~09,i~ 1-1/: 12 13 .... 672~ ..7.6 . 47 4.4 "9".8 1'200 '5 Il-l/: 14 14 7200 76.5 48 4.g '."9 6~i2~00~ 4 '2 i5 ........ · :-~15__~ .7~11 ..... 77'. 50 4.~. 9 5'11500 4 "~ 2 16 ' ' . '16 --~800. 78 .53 4.6 9.5"11500 5 ...... 2 1~ ..... , . .,. __.17 ,,8065, 77 .51 ,.4.8 9.6 12000 4 1-1/: z5 ... 18 , s163 ,76 ~0 4,.8 9,~12000 4 ~-1/~ 14 "' t.19... 8528 . 77 45 4.6 '9.6 12500 7 1 13 ......... .... 20'. 8921 i 77. 49 4 5 ' 9'~5 1~000" 5 1-1/: 15 21 9204" 7'7 53 4.6 '9'9 120ob 4 1-1/: 15 .... -'. , . 22 9435 77 54 4.5 9.9 12000' 5 1-1/: 14 ' 23 9~8 77. 44 4.6 9.6 12000 '5'. '1_1/~ .~4 . . 24 .9909 78.. 50 ... 4.7. 9.5 12000 5 1-1/2 15 _ 25' 10159 78 , 48 -!. 4.8, 9.5 12000 6 1'1/~ i5 .... . '' _ 26 10284 . 77 .... · 51 .... 5.1 9.5 12000 7 1-1/~ 1~ ...... ..... 27 10529 76 60 5.0- 9.3 12000 I 6 1-1/: 14 ' ' 2$ 10700 ~ 75.~ ~2 '~.0 9.312000I '6 1:1/ 14 .... . 29 10700 75.5 52 4.8 9.6 12000 6 1 13 %og'ging. ' ' 30 107.00 75.5 54 4.9 9.4 12000. 5 1 .13" W&ll kicked':'while rng csg. _7/1/69 10700 i75.5 55 4.9 9 4 12000 5 1 13 2 si 47 i .... 5.2 9.4.i2500 ~. i lZ ........ 3 10778 78 ~ 46' ' 6.2 ....1'0.5 12000 4 1 15 ..... ~' 4 10918 74 48 5.6 10,5 125~0 6 3/4 12 ' " .' · , 5 ...11100- ?'3 46 5.4 i0,~ 12000 5 · 1/2 '12 ..... ,. ., 6 11150 .73 47 5.2. 10.5 12000 5 1/~ 10 _ ~. .11.250 .... 73 49 5.4 10.4 12500 6 1/2 12 ' " 8. !I~51 .72.5 61 4..8. 10.~i.12000 · 6 1/2 12' Circ for log~' " 9 11451 72 61 4.8 1~.5 12"000 6 1/2 12 'Loggihg' ' ~ 1~ .11451 .... 73 ..... 42 .12.6 12 12000 3 1/2 12 ........... _ 15 .. 11345'.' 73 Sall water . ' ...... - ' .... , , , · ..... · -- . .... , · .. · I " '-- .... ..... . , ,, , , . , .. · . , ,, ,. ,, ..... ............. . .... ..... , . , , ,. , ..... .... . · · , .. , .... , . , - , . , . ". . -- -~ ..,,. :~,,, : ': . . .. '. , , . - i ' ' ........... · ' ~ 1 · , . i,. .. ............ : : ..... ,.. ' , ....... · . · .... · , . · · -- .. , i, , . ., , _ .,. .' ' ~ .... . . -- , ,. I ...... .... , ..... , :. · UNI{JIN UIL ~U. UI- ~P,i_ii-ui~l~it~ /-~ ' WELL RECORD PAGE: NO..i 4 LEASE Trading, Bay ,iU~lit State WELL NO. i9-30 FIELD McArthur River . CA ;ING & TUBING RECORD i'l S~Z~ ''WEIGHT ,. THREAD~ 'GRADE DEPTH, ~ REMARKS 'l ' ..... I' ~7-3/4" .312 Wal2 spiral wl{! 520 · . [3~3/8" 61# seal lock J255 4779 Cmtd w/2000 sx BJ + 200 sx "G" w/2% Cac12 cmt circ 9-5/8" '~7# & 4'~.5# buttress N & Pti0 9866 See'csg detail 7" "29# '" buttress N-80. ~ 11444. See csg 'detail ' I . . .... ...... . . . PERFORATING RECORD DATE /18/69 1R ' . INTERVAL ~.T.D ..... 9537-956,3 ~ 9588v9610 9660-9681 9702v9766 _ Middle KenaJ 9824-9857 ~ 9878-9892~ J 9956-9977- INITIAL PRODUCTION ...REASON "G" Zone PRESENT CONDITION · DATE" INTERVAL ' NET OIL CUT GRAV. C.P, T.P. CHOKE MC~ GOB' REMARKS ., · ,, -. _ · · · . , __ , , ,, , - . · _ , , · ,, , · WELL HEAD ASSEMBLY TYPE: Shaffer "KD" w/2" S.E. outlets 12" 900 cAsING HEAD: Shaffer 12" Nominal 9-5/8"-Model K.D. K.S. CASING HANGER: CASING SPOOL: TUBING HEAD: Cameron DC-B12 12"-3000# x 10" 5000# w/5000# Studded outlets TUBING HANGER: Dual DCB 10" Nominal with 3-1/2" x 3-1/2" buttress on 5-3/64" centers. TUBING HEAD TOP' 10" 5000f/ Tree MASTER VALVES: Came'ron Iype "F" Gate dual string solid block log tr6e w/2- 3-1/8" bo~e master valves with 2 3-1/8" bore wing valves UNION OIL CO. OF CALiFOrNIA drlli~lNg RECORD- SHEET D PAge NO. 1 LEASE State blcArthur River I~ELL NO. G- 30 FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DAte 5-24-69 25 26 27 28 29 3O 31 6- 1-69 2-3 5-6 E. T. D. 490 530 530 692 1,858 2,257 3,008 4,751 4,815 4,370 Move rig from G-14 workover to Conductor 44, Leg #2. Spudded 15" hole at 9:00 p.m., 5/24/69. Found bottom at 335'. Some .rough drlg at,btm conduc- tor 365' Drld-to 490' Drld to 530'. Ran conductor mill 5 worked over shoe at 565'. Ran 22" expand- ing h,o. Opened hole to 415'. Finished o.h. to 530'. Ran 17-3/4" csg to 365' where it stopped. Ran 5" d.p. inside of csg and worked csg to 412' - unable to run further. Pulled csg ~ d.p. out of hole. Ran 2 h.o.'s and cond. mill to 550'. PO~. Ran csg to 412'.where it stopped. Ran 5" d.p. inside of csg and worked thru tight spot. Set 17-3/4" spiral weld csg at S20'. Cmtd w/2S0 sx "G" cmt plus SO0 sx "G" w/2% CaC12, all.mixed w/inlet water. CIP at 5:45 p.m., S/26/69. WOC 6 hrs. Rigged down riser ~ cut off csg. Nipple up 20" hydril 17-3/4" Casing Detail Howco Duplex Shoe 13 its. 17-3/4" csg (.312" wall) Total casing Above R.T. Casing set at 2.30 520.00 522.50 2.50 520.00 Rig on standby. WO orders. Rig on standby - wo orders 12 hrs. P.U. drlg assembly. D & S 12-1/4" hole to 692'. Ail' surveys taken with Sperry Sun gyro. D 5 S 12-1/4" hole from 692' to 1858'. Surveys taken w/Sperry Sun Gyro. D & S 12-1/4" hole to 1980'. Dymadrld from 1980' to 2257'. D 5 S 12-1/4" hole from 2257 to 255'. Dynadrld from 2551 to 2698'. D 5 S from 2698 to 5008'. Cont'd drlg 12-1/4" hole to 4751'. Cont'd drlg 12-1/4" hole to 4813'. Opened 12-1/4" hole to 17" ~rom 530' to 2480'. Con't o.h. to 4370'. O.H. to 17;' to 43!8'. Circ hole, made wiper trip. POll 5 ran 13-3/8" csg set at 4779'. Cmtd w/2000 sx B-J mix 5 200 sx "G" w/2% CaCl2. Cmt circ. 13-3/8" Casing Detail From To Length No. Jts. Description 4779.0--------~4776.40 2.60 - Baker "G" Shoe 4776.40 4736.94 39.46 1 13-3/8", 61#, J55 Seal Lock csg 4736.94 4735.07 1.87 - Baker ':G" Collar .. 4735.07 57.00 4698.07 123 15-3/8" 61#, J-55, Seal Lock csg. 57.00 0 Landed below R.T. Totals 4'737.53 124 its. 13-3/8" csg. UNION OIL CO. OF CALIFORNIA DRILLING RECORD- SHEET D PAGE NO. 2 LEASE State VV-ELL NO. G-SO FIELD · ~.IcArthur River DATE 6;- 8-69 10 1i 12 13-17 18 19-26 27 28 29 30 7- 1-69 E. T. D. 5.,090 5,313 5,876 6187 8065 8163 10,284 10,529 10,680 10,680 10,700 10,700 DETAILS OF OPERATIONS. DESCRIPTIONS ~ RESULTS CIP at 1:30 a.m., 6/8/69. 'WOC. Nippled down hydril'& cut off csg. Rig released at 6-00 a.m. to move to G-18 and perf addtn'l gas sands. Rig rleased at i2-00 midnight from G-18. Move back & nipple up BOP. Laid down 14 its slick h.w. spool on new sand line. Drld float collar ~ tested pipe rams ~ hydril to 1SO0# ok. Drld. 'Dynadrld from 5219 to 5305'. Drld 12-1/4" hole to 5313'. D & S 12-1/4" hole to 5845'. Dynadrld to 5876'. Cont'd dynadrlg to 5927'. POH for d.a. change. Drld to 6187'. Drlg and surveying 12-1/4" hole to ~065'. Left Grant roller and pin in hole. P.U. Drlg w/12-1/4" bit to 8077'. Globe basket' and RIH to fish at 8077'. Made 3' over fish. Chain out of hole. Rec'd cutter and pin. Made up new bit. D & S to 8163'. D & S 12-1/4" hole. Drlg 12-1/4" hole. D & S 12-1/4" hole to 10,700'. Circfor logs. POH & RU Schlumberger & ran DIL & Density logs. ~vVhile running Sonic log, stuck for 2 hrs. 'vVorked tool loose & RD' Scl~lumberger. RIH & drld 10,680 to 10,700' &circ to cond. hole for 9-5/8-. Ran 9-5/8" csg to 9865' when well blew out. Closed rams & circ. thru choke manifold. 76f~ mud in, 62q% out Cont'd circ. and building mud wt. In 804f, out 76~. Opened rams & cont'd circ. to balance out mud system. %A;ell dead. Attempted to. run csg to bt'm. Unable to move csg. RU Howco & mixed & pumped 850 sx B-J mix + 95.0 sx CFR-2 mixed w/fresh water. Bumped plug w/2000~. Floats would not hole. Shut in Howco head & closed ... rams. CIP @ 3-00 p.m., 7/1/69. %AlOe '9-5'/8 "' Casinq Detaii From 'To Length No. Jts 9865.68 9863.12 2.56 - 9863.12 9820.62 42.50 1 9820.62 9818.66 1.96 - 9818.66 7069.00 2749.66 69 7069.00 5859.33 1209.67 29 5859.33 36.30 5823.03 142 36.30 -0- Landed below R.T. Totals 9824.86 241 its. Description Baker "G" Shoe 9-5/8", 47~, P-110, Buttress Baker "G" Collar 9-5/8"'47~, P-119 Buttress 9-5/8"'474f, N-80 Buttress 9-5/8" 43.5~, N-80 Buttress UNION OIL CO. OF CALIFORNIA DRILLING RECORD- SHEET D PAG= NO., 3 LEASE State WELL NO. G-30 FIELD . McArtl~ur River DATE 10-11 E. T. D. 10,700 10,849 11,097 11,118 11,262 11,400 11,451 11,451 11,451 11,349 ED DETAILS OF OPERATIONS, DESCRIPTIONS &.RESULTS WOG w/rams closed 12 hrs. Cut-off 9-5/8" csg .& nipple-up. Tested BOP rams w/1500~.ok. RIH - rubbering d.p. Drld float collar 6, shoe. Cond mud. Drld 8-1/2" hole to 10,894'. D 6, S 8-1/2" hole to 11,097'. Drld 8-1/2, hole to 11,118'. POH for'bit change· Unable to get back into 8-1/2" hole at 10,700'. RIH w/8-1/2" hole opener. Drld off shoulder frOm 10,700' to 10,720'. RIH w/8-1/2" bit. Reamed from 10,720' to 10,799'. Cont'd reaming hole to 11,118'; had some problems w/hole sloughing from 10,850 to 10,950'. Drld 8-1/2" hole to 11,262'. . Drld 8-1/2" hole from 11,262' to 11,337'. POH for N.B. of fill on btm. Hole sloughing. Raised vis from 48 to 61. hole to 11,400'. RIH 120 ft Drld 8-1/2" D 6, S 8-1/2" hole to 11,451'. Circ'd 15'mins. Made short trip into shoe of 9-5/8" csg. Ran back to btm. 25' of fill on btm. Fill will not pump out without rotating. Circ'd hole clean. RU Schlumberger. Ran DIL, Sonic, 6, Density. Schlumberger TD 11,450'. Completed logging 6, taking sws. RD Schlumberger. RIH w/d.a. Cond hole for csg. Spotted 60 bbl gel pill on btm. 'Ran 40 its 7" csg · w/TIW, liner hanger. Shoe set at11,444' w/top of liner hanger at 9785' Circ'd thru liner for one hr 40 SPM @ 1000f~. Set liner hanger & released from same. Circ'd an additional 5 mins w/rig pump. Shut down 6, switched over to Howco cementing unit. Pumped 30 cu.ft, water w/pressure increasing to 2,000 psi. Unable to circ. Pumped fluid away @ 2600 psi. POH. Rigged up Schlumberger. Perfed 4-1/2" holes from 11,375' to 11,377'. 'Ran Howco EZ drill retainer on 3-1/2" dp stinger on 5" d.p. Set retainer at 11,349'. Circ'd around liner at 2700~. Pressure dropped back to 1525f~ while circ'g at 275 gpm. Mixed 1000 sx "G" cmt w/l% CFR2 w/fresh water and pumped same thru perfs while stabbed into EZ drill. Displaced w/1000 cu.ft, mud. Pulled out of EZ drill and above it 1'0'. Dumped ~5~cu.'ft. .cmt on top' of retainer. Backscuttled excess cmt out at 2600~. As an estimated 175 sx cmt had been dumped, flange at top of riser cut out. Opened rams, picked up Kelly, circ'd. thru d.p. until worst contaminated cmt dumped. POH to 2067'. Cond' mud. POH. RIH w/Howco retrievable tO 914' and set same. Removed BOE's and riser assembly. WOC and riser assembly. LEASE -State UNION OIL CO. OF CALIFORNIA DRILLING RECORD' SHEET D PAGE NO, I ~ I II · · WELL NO. G-30 ......... FIELD McArthur River DATE 7-12-69 13 14-15 -16-17 E.T.D. 11,348 11,348 Bottom Retainer TD 11,45 ~i Retn'r 11,349 f~2 Retn'r 10,600' ~3 Retn'r 9970' 11,345 DETAILS Of OPERATIONS, DESCRIPTIONS & RESULTS 7" 'Liner Detail 7" TIW Shoe '1 jr. 7" 29~ N-80 Buttress csg 7" Baker Mod :'G" Collar 7" TIW Ldg. Collar 39 jts]" 29~ N-80 Buttress csg 7"xg.-5/S'' TIW Liner hanger Landed below zero Top 2.35 11,441.65 41' 21 11,400.44 1.72 11,398.72 1.05 11,397.67 15~J7.56 9,810.11 24.58 9,785.53 9785.53 -0- Bottom 11,444.00 Instld new pressure riser. Tested blind rams to 2400~. RIH. Retrieved b.p. CO to top of liner w/8-1/2" bit and scraper. Cond mud. Tested pipe rams to 2000fF. Tested Hydrill (n.g.). POH. Changed Hydril rubber. RIH w/6" bit and scraped to 11,333', CO to top of retainer at 11,348'. Cond mud. Ran Schlumberger Gamma Ray Correlation log. Perfed 4 hfs at 10,650' (DIL). Set cmt retainer on dp at 10,600'. Squeezed w/200 sx, 1% CFR2 "G" cmt mixed w/fresh water w/100 cu.ft, water ahead and 50 cu.ft, water behind. Closed on 100 cu.ft, water. Max psi=3500fF. Standing psi=2400~. Cleared holes, pulled out of retainer, circ'd. CIP at 1:30 p.m. 7/13/69. Pumping time 2 hfs, 20 min. IA/OO 6 hrs, stabbed into retainer. Squeezed 200 sxs 1% CFR2 "G" cmt mixed w/fresh water w/100 cu.ft. water ahead and 50cu.ft. behind to a max psi of 4~00~, and a standing psi of 4400fF. Cleared holes by 50 cu.ft, water and 30 cu.fto mud. PO of retainer. WOO and circ. Stabbed in to retn'r at 10,600'. Pressured up to 5000~, Standing ok. POH - perfed 4 l~oles w/Schlumberger 4" gun at 10,020'. Set retainer on.d.p, at 9970'. Mixed 200 sx 1% CFR2 "G" cmt. Unable to get standing pressure above 325'0 psi. Cleared holes, circ and %Aroc 8 hrs. Mixed 200 sx 1% OFR2 cmt w/fresh water w/100 cu.ft, water ahead and 50 cu.ft, water behind cmt. Squeezed to a standing pressure of 4200 psi as tool was cleared. Pulled out of retainer at 4200 psi up at 2:00 a.m., 7/15/69. Backscuttled d.p. clear. POH. Made up 8-1/2" bit and scraper on d..'p, Ran in to liner top. Circ'd btms up.,. POH. Changed over to 73~ salt water. Rigged up Schl~tmb~rg~r, ~erf'ed w/4"' hyper-jet guns as follows: 10,712710,728', 10,828-10,838', 10,860-10,875', 10,883-10,891', 10,895-10,899', 10,902-10,914'. Ran Howcotester on 3-1/2" and 5" d.p. Set tester w/packer'at 10,670', tail at 10,683'. Opened for IF. Peris previously squeezed at 10,650' were believed to nave communicated withperfs at 10,712'. Fluid in annulus dropped. Re-set pkr at 10,616'. w/tail at 10,629'. Opened for ID at 1354 hrs. No fluid or gas to sic. Closed tool for ISIP at 1425 hrs. Opened tool for flow at 1555 nfs. Light to med. blow and gas to sic at 2100 hrs. Blow dcrsd entirely. Closed tool for FSI? at 2400 hrs. Reversed fluid through test separator as follows: 30 bbls, cut 9.2% w/l% mud and 31. dry gravity. 141 bbls 45.5% Cut w/20% mud and 31 dry gravity. Total recovery 171 bbls. Esti- mate loss of 25 bbls water around packer while re-setting aboQe squeeze peris and due to communication between peris. LEASE State UNION OIL CO. OF CALiFOrNia DRILLING RECORD' SHEET D PAGE NO. 5 WELL NO G-30 FIELD McArthur River DATE 16-17 (Cont 18 19 20 E. T. D. 11,345 11,345 11,345 DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS IHP 4813 IFP 16Y3 IPP 1370 FFP 3685 FFP 1627 FCIP 4356 ICIP 4197 FHP 4~13 RIH w/bit & scraper. Circ'd btms up to ck for gas bubble. 160 bbls of 74f~ "Protecto-Mul" from 11,345 to 8,400' down 3-1/2" d.p. & 6" d.c.'s. Spotted . POH. Laid Perfed West Foreland & Middle Kenai "G" Zone with 4 hpf w/Schlumberger 4" carrier nyper jets. Reperfed zones between the intervals of 10,712 to 10,914' that had previously been open for DST ,(see perforating record sheet "C"). RU & commenced running 3-1/2" tbg. Ran &landed dual strings of 3-1/2" tbg (see tbg detail). After installing ball valves, the strings were run dually in order to protect control lines. Nippled down BOP's. Installed & tested dual tree. Tested w/5000~ ok. Tubing detail attached. Displaced salt water & Protecto-Mul w/diesel. Immediate shut in pres- sure=750~. Dropped ball and pressured long string to 3600~. No surface indications of pkrs setting or shearing shear sub. Bled annulus to zero w/3000~ on long string and 7504f on short string. Ran sinker bars & jars on wire line. Found ball in shear sub. Sheared out same. Opened snort string to well clean tank. Produced 9 bbls in one hour. Flow pressure was zero on 124/64" choke. All other pressures remained the same. Long string 760f~, annulus zero. Shut in well for rig move. RIG-RELEASED 12 NOON 7/20/69. ~ .~/ Packer ~.stallation Record OlVI~;ION OF DRESSIER INC3tJSTI=qlE.,~. INC.. ,ox ,,o,. ~,, ?~.~ .~. Tubing Detail Report Prepared For ....... Company ~ Date ' Lease...... ' Well No.' j,Fie'l~ , ,, Co. or Parish . State ] ~ New Completion ' 'J ~ Workover ' Siz; Weight' ' Grade Thread Depth Si ze - Weight Grade Thread Depth . · TyPE OF TUBING FOR STRING NO. I si,." I w.,~h~ J O,.d; I Th,..d j'Depth ' TUBING. ~ I ~ ~.~ / ~ ~ , . ,, .V~. cx. ~7~ -. ~ . ~X ' ~70 ~ ~ " I'~_ y,: ~o ~,~ ~~/ · ' ,. / r /~ ........ . .__ . .... ~~' ~ ~/ Packer !~tallation Record ~,v,~,o.o~o.~.~.,~o~.~,.. ~ Tubi g Detail Report BOX 1106 · DALLAS, TEXAS 75221 ~ 'J~repared Fc~r .... .~! Company Dote Lease . . . Well. No. ~ ~Field - ~-~o I Co. or Parish ~ State I ~ New Completion '" 'J ~ Workover .... Si ze ~ Weight Grade Thread Depth CASING . ...... Size Weight ' ' ' Grade Thr'ead Depth ' " LINER ,, , TYPE OF TUBING FOR STRING NO. J Size' J'wei~ht J 0,~ I Th,,~ I Depth . I l, . / ,.~4. ~ ~ ~o ~~ ~./v- / I i i : .... , . .... . ..... . . .... [' ' . D,~ .... FM ~~~.~'~ ,~/ Packer l~stallatio. Record DtVL'~IC~N OF C~RE$$ER INDUSTRIES, lNG. "BOX 1106 ® DALL. AS, TEXAS 75221 Tubing IJetaii Report Prepared For Company .. Date .h . ~"" ~ ,~, /~',. U,~, ~,~ 0~ ~. ~ ~ ~ Z ~ ~ ~- z o. ~ ,~ ...... , Lease Well No.' I ~Field , Co. 0r Parish . State I ~ New Completion . Size Weight Grade Thread Depth CASING _ Si ze Weight Grade Thread Depth LINER . I TYPE OF TUBING FOE STRING NO. , I ....................... I ........... :?: .............. I .................................................................................... , .................................................. .... -'J~o ~ X ~ 7o . I& Z' . , L , I I Vv dy, ' ,~7o .76~ f~ 766q,~ . , .... Form No. P~4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMFr IN DIIPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER T -- 2. NA!~E OF OPEBATOR Union Oil Company of California 3. ADDRESS OF OPI~T~DR 507 W. Northern Lights Blvd., Anchorage, Ak. 99503 4. IX)CAnON OF W~3~ Conductor #44, Leg #2, 1876'North & 1378' West from SE corner Section 29, TgN, R13W, SM. · i.n.I, AA OKG 50-133-20187 vtV I"IWK ~--_/7' ADL 187230 REt /'-~ ?. IF INDIAI,J', ALOTTEE Pi{ TI~BE nil 8. L~-'IT,F.~A~ OR LEASE NAJ%~--~ Trading Bay Unit 9. WELL NO, State G-30 (11-33) i0. ~-,~nr~ A_WD POOL. o~ wIh~t Foreland McArthur River - Middle Kanai "G 11. SEC.. T., R., M., (BO/~FOM HOLE OBJECr~V~ Section 33, T9N, R13W, SM 12, PERMIT NO. 69-47 ]3. REPORT TOTAL DEPTH AT END OF MONTH. CI-IA~qGES IN HOLE SIZE, CASING ~ CE1VIENTING JOBS INCLUDING DEPTH SET AND VOLU'NIES USED, PERFORATIONS, 'rESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE A.ND SIDE-TP~ACKED HOLE ANT) A~Y PTI{ER SIGNIFICANT ~F.S IN HOI.~ CONDITIONS. TRADING BAY UNIT STATE,. G-30 (1!-33), MAY 1969 Moved to Conductor #44, Leg #2. SPUDDED @ ~ .PM 5~.24/69. Drld 15" hole to 530'. Opened 15" to 22" hole 0'-530'. Ran 17-3/4" csg. Stopped @ conductor shoe @ 365'. Worked csg to 412'. Unable to work csg deeper. PUlled csg. Reran 22" HO to 53~', ran 18-7/8" conductor mill to 530'. Ran 17-3/4" csg, stopped @ 412'. PU Howco Stab in & RIH on HW dp. Stabbed into shoe. Circ& wrkd pipe thru tight spot. Ran'17-~/&" csg & hung w/shoe @ 520'. Cmtd thru shoe w/250 sx "G" cmt w/2% gel followed by 500 sx "G" w/2% CaC12. Good returns to surface. CIP 5:45 pm 5/26/69. WOC 6 hrs. Removed riser. Cut off 17-3/4" csg & instld 20""~ydrill. WOC. Press tstd csg. PUmped to formation w/350#. No circ te surface. RI w/Howco stab in on dp. Stabbed into duplex shoe. -Sqzd shoe w/200 sx Class "G" cmt. CIP 12:15 pm 5/27/69. WOC 6 hrs. Press tst 600# OK. RIw/d.a. Drld 12-1/4" hole to 1980' POH. RI w/DDrl. DDrld to 2257'. POH. RI w/angle building assembly. Drld 2257~2551. Now POH for DDrl. 14. I hereby certify/ he ~e and correct S,G~ /~r~/,,, / ~ .... ~T,-~, Dist. DrlK. Supt. DA~ 6/10/69 NOTE--Report on this ~/m is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines ~/Minerals by the 15th of the succeeding month, unless otherwise directed. Form REV. 9-30-67 STATE OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to dr[Il or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PER/VIIT--" for such proposals.) OIL ~ OAS ~ WELL WELL OTHER 2. NAME OF OPEiRATOR Union Oil Company. of .California 3. ADDI~ OF OPEllATOR 507 W. Northern Lights Blvd.~ Anchora~e~ Ak. 99503 4. LOCATION OF WELL Atsurface Conductor #44, Leg #2, 1876'N & 1378'W from SE corner Section 29, T9N, R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 99' RT above MSL 14. Check Appropriate Box To [nd:i'cate Niature of N~oti'ce, Re NOTICE OF INTENTION TO: 8. UNIT, FA_R1V~ OR LF_~SE NAIVIE Trading Bay Unit 9. W,~,L 'NO. State C-30 (11-33) 10. F~J=D A/FD POOL, OR WILDCAT R' e"-''~a±e Kenai McArthur zv r- ~ & W.Foreland 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sect. 33, T9N, R13W, SM. 12. PERMIT 69-47 zort, or 'Other 'Data SUBSEQUENT REPORT OF: REPAIRING WELL TEST WATER SHUT-OFF PULL OR ALTER CASINO WATER SHUT-OFF FRACTURE TREAT MULTIPLE COMPI,ETE FRACTURE TREATMENT ALTEI%ING CASING SHOOT OR ACIDIZE ABANDONS SHOOTING OR .ACIDIZING ABANDONMEN'T* REPAIR WELL CHANGE PLANS (Other) (NOTE: Report results of multiple completion on Well (Other) Change location & name Completion or Reeompletion Report and Log form.) ,.__ 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting proposed work. , 'Change of Surface Location & well name. programmed. Bottom holelocation remains as originally ORIGINAL PROPOSED: TBU State G-21 (11-33). . Surface Location: Conductor '#12, Leg #3' 1803'N & 1407'W from SE corner Section 29, TPN, R13W, SM. ACTUAL LOCATION: TBU State G-30 (11-33) Surface Location: Conductor #44, Leg #2, 1876'N & 1378'W from SE corner Secti°n 29, T9N, R13W, SM. 16. I hereby certify thaftt~ for~g~i~ ts_ tr!~p and correct Dist. Drlg .Supt SIG~D TITLE · ' APPROVED BY CONDITIONS OF APPROFAL~ IF DATE DATE 5/29/69 See l~nstrucflons On Reverse Side Approved Returned DZ~$ZaH O~ O~ ~ T~din~ Bay Sta~:~ G-21 (11-]3) ~nion Oil ~omp~ny ot ~ll£oFnte ~. So McAlt8~er, Landman Oil ~y of ~l~is Deu81i St~ee~ Aur. lm~aje, .Aissk~ ~3 Dear Sir: requtEed belme the ~ of the ~t:huz Rt~ lhsSlock Oil Pool the eve~ of dioeovery ~ m~ undefined pool a bs~tng ~1I be require~ in order, ~o deflne ad establish fis~ rules f~or the: pool, In aecos~l~e utth Couoervat:iou Order Ho. 71, cement is required .~o .cover. tbe~ ~le ~ Gas Pool, plus ~)0 £eet. truly yours,, ,Homer Lo Burrell FORM SA - ~ B MEMORANDUM State of Alaska DATE FROM: SUBJECT: FORM SA- I B MEMORANDUM TO: I-- FROM: ~ 'J, Je ~J. State of Alaska SUBJECT: Form ,REV. 9-30-6V SUBMIT IN TRIP~ (Other instructions reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 11[. TYPE OF WORK DRILL [] 2. NAME OF OP~TOR Union 011 Company of California 3. ADDi:GESS ~ OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. DEEPEN ['-J PLUG BACK [-I M U LTIPI, EZONE [] LOCATION O'F WELL A~:surface Conductor #12, Leg #3, 1803'N & 1407'W from SE corner Sec. 29, T9N, R13W, SM' At pro~osed prod. zone Top "G"' 520'S & 550'E from NW corner Sec. 33, T9N, R13W, SM ' 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR.POST OFFICE* 25 air miles NW of Kenai, Alaska 14. BOND INFORMATION: TYPE Statewide Suretyand/or No. United Pacific Insurance Co. B-55572 15. DISTANCELOCATION FROM TO NEAREST PROPOSED* [16. NO. OF ACRES IN LEASE PROPERTY OR LEASE LINE, FT. '~ I (ALSO to nearest drig, unit, i£ any) 1, 320 ' 3 840 18. DISTANCE FROM PROPOSED LOCATION* 9. PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETE;D..i 450'MD & 10 600'TVD OR APPLIED FOR. FT. 1,420 ' I 1, , 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 99' RT above MSL API 50-133-20187 6. LEASE DESIGNATION AND SERIAL NO. ADL 18730 ~. IF INDIAN, ALLOTT~ OR 8. UNIT~FARM OR LEASE NA1VI~ .. Trading Bay 9. WELL NO. State G-21 (11-33) I0. ~IELD AND POOL, OR WIL~D/~A4r 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T9N, R13W, SM 12. ,~o,~ $100,000.00 ]7. NO. ACRES ASSIGNED TO THiS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL ST,kRT* July 1, 1969 23. PROPOSED C~SING AND CEMENTING PROGRAM ,. SIZE OF HOLE SIZE OF CASING': :WEIGHT PER FOOT GRAi)E r' sETTiNG DEPTH " 'QUANTiTX OF CEMENT 26" 20" 94# H-40 600' Otc 1500 SaCks cement to surface:;.~ 17~" 13-3/8" ' ~t# J-55 4800' oiu 3500 " 12%" 9-5/8'.';,,~:: 40#, 45.S~ N-80,~ 990,0' 1200 47# P- lr!0r 8~" 7" Liner' 29~ N-80 9800'-11~450" .350. " . Cement 20" casing in 26" hole at 600'. Install 20" hydrill. Cement 13-3/8" casing in 17½" directional hole at 4,800'. Install BOPE. Drill 12~" directional hole to 9,900'. Run electric logs. Cement 9-5/8" casing'at 9.,9.00'. Drill 8½" directional hole to 11,450'. Run electric logs. Cement 7" Liner from 9,800' - 11,450'. Block squeeze above and below Hemlock zone; 'complete. for production through dual 3½" tubing string - Middle Kenai "G" and West Foreland zones Bottom Hole Location: 1,360'S & 1300'E from NW corner Sec. 88, T9N, R13W, S.M. m ABO~ SPA~ DES~BE ~OPOSm. P~G~: If ~1 ts.~ deemn or ~¢g ~~e ~,~g.p~s~¢) p~d~ive ~ ~d ~ proposed ~ew produ~ve ~. I~ pro~ ~s to ~fll or d~n d~e~.on~ly, g~ve pe~meno ~ ~ ~~ ~a~ns ~a meas~ ~d ~ue venal dept. Give blo~ut preventer program. 24. I h~y ce~ify that the~goi~ is ~u~n~rr~ DIVISION OF OiL AND GAS s~ .... - ~ ~April 17~ 1969 a~c,~.~ m~ Landman (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: A LES AND CO C PSRE .I . ....... ....... J <'- ~ (" :'~"'~','", 0 "~,'~ ,, ": '"']1 J _ . p~ so_~ ~ - ~,7 ~ ~ov~ ~.~ April 30, 1969 ~ . , ~ D~v. of 0~1 and Gas ~ ~pr~l 30. 1060 APPROVED BX_ *See Incubi°ns On Reveme Side G-17 (~4-19) ARCO WFU $ TD 9768' J9 .30 K-I RD TD 12,570 G- 1.5 (34-t9) G-13 (3? -~0) -19 \ '\ ( 32:- 29) \ \ K-4 (14-z;) (32-21) ~K-9 G-4 (22 G-I (32-28) G-lO (14-29) (34- 29) ( 32-32 ) G-7 ( 14-28 ) u,, TMD t ~1-55) PBHL TVD 10~600' TMD 11~4§0' ( s4 - G-8 (32- 33) D-II UNION - MARATHON ADL- 17594 , D-I (34 - 32) · D-3 (42-e) JNION D-7 ( 14-$3 T 9N - RI3 W (34-33) OIL COMPANY OF CALIFORNIA ALASKA DISTRICT / DIVISION OF Oil. AND aAsI I D-5 WELL LOCATION MAP UNION OIL CO. OPERATOR UNION TRADING BAY STATE UNIT (11 - 33) D&'F ~ , MAR, 24,1969 ...... l ~c^~, ,~": zoo,o' o ~oo CHEC!?,~.LIST FOR NEW WELL PERM[TS ~ec: in a ~u~.ine. d pool ............................... Yes 19, I.;':;.~ ...... I a'i ] cas:.i~S give ..... ,;;qu.,:~t.e i.n *-~-,.,.~-.<~.i- se and Wit ~ (:<::::::::i: cc,'ver 611 po*:'il)le -~ ': ........... p,. o,~u,~ sire horizons ' Wit1.. .,<' u"',' :,. '_ ~-,. c.-,~., casing cover atl. fresh, water zones -~ ~.c':{.C'(Dt ~ .... co <,*~ Does J;O).'E h::ve :>.,....~. ', t, le .... u:u rating (;s n {:l':'i ,.: l. d ~ d i ly