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Home My WebLink About171-020Schwartz, Guy L (DOA) From: Sent: To: Schwartz, Guy L (DOA) Monday, January 26, 2015 9:21 AM 'Juanita Lovett' Cc: Ted Kramer; samantha.carlisle@alaska.gov Subject: RE: Withdraw Sundry: A-26 PTD - Sundry # 314-090 Juanita, AOGCC will withdraw sundry 314-090 as requested. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office SCANNED JAN 2 7 2015 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.aov). From: Juanita Lovett [mailtoJlovett0)hilcorp.com1 Sent: Monday, January 26, 2015 8:56 AM To: Schwartz, Guy L (DOA) Cc: Ted Kramer Subject: Withdraw Sundry: A-26 PTD - Sundry # 314-090 Guy, Please withdraw the above mentioned sundry. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8332 Email: ilovett@hilcorp.com • OF 'Pk, ��\I%% As T'iih STATa ,-- L, 4.)) _ �._ ._ 7` ,----;t'- ,-7;\"� ,1, C f / /' r ` 11 j i st - 333Ves� Se ;� 1 __,�'�-- -- ven'h Avenue " 9 y GO\ 1 RNOR IAN ARNl i i, Anchorage, Asa 99501 3572 Q u� ionfn: 907.279 1433 SCANNED AUG 0 6 2Cj4 Ted Kramer Oaf)Sr. Operations Engineer 17 Hilcorp Alaska, LLC ` 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C Oil Pool, Trading Bay St A-26 Sundry Number: 314-090 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, . P ,,,,,,,(1-,-- Cat y P Foerster Chair DATED thisday of February, 2014. Encl. RECEIVED FEB 1 8 20 4 STATE OF ALASKA /�TS /t ALASKA OIL AND GAS CONSERVATION COMMISSION ,�+,�/'� GG APPLICATION FOR SUNDRY APPROVALS �! 20_AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod Cl Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate 0 Pull Tubing El Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development 0 171-020 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service CI • 6.API Number. Anchorage,AK 99503 50-733-20230-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA IAau s I441:D Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay St/A-26 a 9.Property Designation(Lease Number): 10.Field/Pool(s): Vi/3ADL00187314 TradingBE;,y t mcI , J1_ I-€A6.i C ©;l 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): . • 8,795 - 5,662 • 8,688 5,575 N/A 8,688',8,744'&8,740' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,036' 13-3/8" 1,036' 1,002' 3,090 psi 1,540 psi Intermediate 8,795' 9-5/8" 8,795' 5,662' 6,870 psi 4,760 psi Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic 3-1/2"dual 9.2#/N-80 7,360&7,939 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Pkr:Baker Model A-5 Dual Hyd&Baker Model D Retainer Prod/SSSV:N/A 7,343'(MD)4,659'(ND);7,340'(MD)4,658'(ND);7,920'(MD)5,011'(ND) 12.Attachments: Description Summary of Proposal 0 1 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0- Exploratory ❑ Stratigraphic❑ Development❑ Service 0 . 14.Estimated Date for 15.Well Status after proposed work: 2/19/2014 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended Cl 16.Verbal Approval: Date: WINJ 2 • GINJ ❑ WAG El Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer � Signature 4,'11.17."'N.........._ Phone (907)777-8420 Date 2/14/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so at a representative may witness Sundry Number: \L(\ o:\b Plug Integrity ❑ BOP Test (✓� Mechanical Integrity Test Err Location Clearance ❑ Other: i` 2 SoO � 452) 7:-..,14._ /h Cr- IA- 5�4-1,-L� - , RBDMS�r10 2014 7 Spacing Exception Required? Yes CI No Subsequent Form Required: /O ...L,/oL/ APPROVED BY / `i--- I / Approved by: , - COMMISSIONER THE COMMISSION Date: 2— 2-7- 1� 2J U I �JNA Form 10 403(Re sed 10/2012) App a pc r v r months from the date of approval. Attachments in Duplicate • 14 Well Work Prognosis Well: A-26 Hilcorp Alaska,LLC Date: 02/14/14 Well Name: Monopod A-26 API Number: 50-733-20230-00 Current Status: SI Water Injector Leg: N/A Estimated Start Date: February 19,2014 Rig: Monopod Platform Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 171-020 First Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907)398-9904(M) AFE Number: Current Bottom Hole Pressure: 2593 psi @ 5056'-Calculated from 1/3/81 pressure survey. Maximum Expected BHP: 2,593 psi at 5,056'-From survey above. Max. Anticipated Surface Pressure: Brief Well Summary The A-26 was completed as a dual injector in November of 1972. The short string was shut in due to fill which resulted from back flowing the well after a shut in. Injection was resumed in 1977 but resulted in watering out offset producer A-22 and was shut in. Procedure: 1. MIRU Monopod Platform Rig#56. 2. RU Slickline and shift the sliding sleeves at 7,276'(SS)and 7,884'(LS). RD slickline. 3. Circulate Hydrocarbon off of well with 3%KCL. Insure well is dead. 4. ND Wellhead,NU BOP and test to 250psi low/2,500psi high.(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 5. RU E-line.RIH and cut short tubing string at 7,338'(+/-).Cut the long tubing string at 7,330'(+/-). RD E-line. 6. POOH with 3-1/2"X 3-1/2"dual tubing string and lay down the same. (Note:strings may be pulled one at a time). tiJ---• 7. PU RIH with 9-5/8" RTTS packer to 300'and set. Test same to).1506si. —,-, �.eaf- 1-6 8. ND BOP. RU and change out wellhead to single. !fes- 16"7- 9. NU BOP and re-test to 250psi low/2,500psi high. fa Z-s-l)tlr-,=; 10. RIH andull RTTS Packer. � p -7 11. PU Packer milling assembly. RIH W/washpipe and mill. Burn over dual packer at 7,343'. POOH with mill. 12. PU RIH with packer plucker. Engage Dual packer and POOH with same. 13. PU and RIH with Overshot and latch onto Long String. Work long string to pull tubing out of seals of lower Packer at 7,920'. If successful,go to step 16. Otherwise go to step 14. 14. RU E-line. RIH with Tubing Cutter to 7,915'. Pull tension on tubing string,cut tubing. POOH with cutter. RD E-line. 5. POOH with 3-1/2"tubing string, lay down same. 16. PU RIH with washpipe and milling shoe to packer at 7,920'. Burn over packer. POOH with washpipe. 17. PU RIH with packer retrieving tool. Latch onto packer and POOH with same. 18. PU RIH with bit and scraper,clean out to PBTD(8,795'). Circulate hole clean. POOH with same. • Well Work Prognosis Well: A-26 Hileorp Alaska,LLC Date: 02/14/14 19. PU RTTS test packer. RIH to 6760'and set. Pressure test casing to 1,500 psi.for 30 minutes. Chart same. POOH with RTTS test Packer. 20. RU E-line. PU RIH with GR/CCL logging tool to 8,795'+/-. POH logging well up to 1,036'. RD E- line. 21. PU RIH with TCP perforating guns spacing out as per Final approved Perforation Request Form. RU E-line. Run tie in log. Place guns on depth . Fire guns. 22. PU on guns and circulate out perf gas. Monitor well for 1 hr shooting fluid levels to determine fluid loss. Fluid loss should diminish over time. 23. Once well is stable,POOH with TCP guns. 24. PU Permanent packer and RI well on work string to 6,700'+/-. Set packer. 25. PU completion string consisting of Injection Packer and 3-1/2" polycore lined injection string. Space out and set seals into packer. Hang off tubing. 26. ND BOPs,NU Wellhead and test. L a 27. Turn well over to production. f Do s✓ / �D�....�, �jj /O Attachments: Lc)' �``""�` '� AIT a , 1. Current Well Schematic S-j'�� 2. Proposed Well Schematic 3. Proposed Wellhead Diagram 74- 4. BOP Stack L •!1•11 ` Trading Bay Unit UN76 OCAL Well#A-26 Last Completed 11/6/72 CASING AND TUBING DETAIL RKB to TBG Hngr=36.40' SIZE WT GRADE CONN ID TOP BTM. Tree connection: Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 Surf. 1,036' ;L Tag 412004' 9-5/8" 47 N-80&P-110 Butt 8.681 Surf 8,795' /29/81 Tubing: ' I� LS 3-1/2" 9.2 N-80 Butt. 2.992 0' 7939' SS 3-1/2" 9.2 N-80 Butt. 2.992 0' 7360' SL Tag @ 6045' 8/29/81 •_. . r` JEWELRY DETAIL I i " NO.NO. Depth ID Item '4 I Ii-7 36.75 Cameron DCB Dual 3-1/2"Tubing hangers, I. 1 SHORT STRING li J Ir—tl A 6264' Three(3)Baker 3-1/2"Telescoping Joints, 10.69'long B 7276' 2.75 Otis"XO"Sliding Sleeve C 7343' Baker Model"A-5"Dual Hyd.Pkr D 7358' 2.635 Otis"N"Profile Nipple B cAA7 k E 7359' Shear Sub ° 2 `,,/� btm 7360' LONG STRING C ��< 3 7 3ii3t 1 6265' Three(3)Baker 3-1/2"Telescoping Joints, 10.69'long 2 7305' 2.75 Otis"XO"Sliding Sleeve 3 7340' Baker Model"A-5"Dual Hyd.Pkr D • 1 4 7884' 2.75 Otis"XO"Sliding Sleeve E 5 7920' Locator Seal Assy. 11.65'long 6 7920' Baker Model"D"Retainer Production Pkr. 7 7936' 2.635 Otis"Q"Profile Nipple 8 7938' Collar Guide btm 7939' 1. 2108 Howco DV Stage Collar C-7 FISH LS Juck Pusher f/WO 8740' 10/30/72 - C-7 LS 13.58'Wireline tools 8744' 2/17/73 LS 14.5'Wireline tools 8688' 11/2/73 o C-7 FILL LS Tagged 1"OD tools 6045' 8/29/81 rs C-7 SS Tagged 1"OD tools 2004' 8/29/81 C-7 PERFORATION DATA Accum. Date 4Zone Top Btm Amt. SPF Last Opr. Present Condition .5 -i6,). e.iL C-7 7,502' 7,512' 10' 2 4/24/72 Open 6 .77 Z C-7 7,538' 7,550' 12' 6 11/2/72 _Open C-7 7,582' 7,600' 18' 4 11/1/72 Open 7 C-7 7,660' 7,678' 18' 4 11/1/72 Open 7,678' 7,680' 2' 4/21/72 Cmt sqz'd 8 C-7 7,720' 7,744' 24' 4 11/1/72 Open 47-57 7,940' 7,970' 30' 2 4/26/72 Open 47-5 7,970' 7,972' 2' 4/21/72 Cmt sqz'd Fill tagged on 2/16/74 of - --- @ 8688' _ 50-3 8,308' 8,320' 12' 2 4/26/72 Open cr 53-3 8,320' 8,322' 2' 4/21/72 Cmt sqz'd ,- -,...- ,1\_,ED___ 51-6 8,680' 8,698' 18' 2 4/26/72 Open 51-6 8,698' 8,700' 2' 4/21/72 Cmt sqz'd l KB ELEV=101' PBTD=8,795' ANGLE thru INTERVAL=55° A-26 Schematic 1972-11-06 REVISED:2/14/2014 DRAWN BY: SLT Trading Bay Unit ... H Proposed Monopod Platform Well # A-26 Completed: Proposed RKB to TBG Hngr=36.40' CASING AND TUBING DETAIL Tree connection:Dual 3"5,000# SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surf. 1,036' 9-5/8" 47 N-80&P-110 Butt 8.681 Surf 8,795' I A Tubing: JEWELRY DETAIL NO. Depth ID Item 36.75 Cameron DCB Dual 3-1/2"Tubing hangers, ±6,700' Tri Point Inj.Packer ±6,708' X-Nipple ±6,718' WLEG A. 2,108' Howco DV Stage Collar 1 Perforation Data X 2 Date 3 Top Btm Top Btm Last Present Zone (MD) (MD) (TVD) (TVD) Amt SPF Opr. Condition C-3 C-3 ±6,770' ±6,810' ±4,357' ±4,377' 40 Future - C-4 C-4 ±6,968' ±6,983' ±4,459' ±4,467' 15 Future - C-5 C-5 ±7,053' ±7,270' ±4,504' ±4,620' 217 Future C-6 C-6 ±7,350' ±7,400' ±4,663' ±4,691' 50 Future C-7 ±7,490' ±7,560' ±4,744' ±4,785' 70 Future - C-7 C-7 7,502' 7,512' 4,751' 4,757' 10' 2 4/24/1972 Open C-7 7,538' 7,550' 4,772' 4,779' 12' 6 11/2/1972 Open - C-7 ±7,570' ±7,605' ±4,791' ±4,811' 35' Future - C-7 C-7 7,582' 7,600' 4,798' 4,808' 18' 4 11/1/1972 Open C-7 7,660' 7,678' 4,844' 4,854' 18' 4 11/1/1972 Open C-7 C-7 ±7,660' ±7,682' ±4,844' ±4,857 Future C-7 7,678' 7,680' 4,854' 4,855' 2' 4/21/1972 Cmt sqz'd +7,704' +.7,758' ±4,869' ±4,902' 54' Future C-7 7,720' 7,744' 4,879' 1,893' 24' 4 11/1/1972 Open ±5,010' ±5,055' 67' Future 47-5 47-5 7,940' 7,970' 5,024' 5,045' 30' 2 4/26/1972 Open 50-0 47-5 7,970' 7,972' 5,045' 5,046' 2' 4/21/1972 Cmt sqz'd - 50-3 ±5,272' ±5,298' 35' -CZN2ST �'t 50-3 8,308' 8,320' 5,282' 5,291' 12' 2 4/26/1972 Open - 51-0 50-3 8,320' 8,322' 5,291' 5,292' 2' 4/21/1972 Cmt sqz'd 51-6 CZN2ST ±8,411' ±8,468' ±5,359' ±5,401' 5/' Future 51-0 ±8,580' ±8,617' ±5,489' ±5,519' 3!' KB ELEV=101' Future 51-6 ±8,668' ±8,726' ±5,559' ±5,605' 58' PBTD=8,795' Future ANGLE thru INTERVAL=55° 51-6 8,680' 8,698' 5,569' 5,583' 18' 2 4/26/1972 Open 51-6 8,698' 8,700' 5,583' 5,585' 2' 4/21/1972 Cmt sqz'd Updated by: JLL 02/14/14 Tubing hanger,Sea board, 11 X 31/2 Monopod A-26 EUE lift and 3 1/2 EUE susp,w/3" 13 3/8 X 9 5/8 X 31/2 Type H BPV profile Bowen cap, 3 1/8 5M N uuMnu Valve, swab, WKM-M, 3 , 0 0 1/85MFE, HWO, FF 401p trim 0-60 Tee, stdd, 3 1/8 5M X 3 1/8 5M Valve, master, WKM-M, 3 - 1/8 5M FE, HWO, FF trim 0 O o Adapter, Sea Board, 11 SM X 3 1/8 5M Stdd top, w/ 5" extended neck pocket — 1.1 III Tubing head, Sea board, 13 5/8 3M X 11 5M, w/2- 2 1/16 5M SSO, X111 '. 14. I� `` I Valve, CIW-F, 2 1/16 5M FE, bushing type bottom prep HWO, AA trim III I Sal it..trt zica' Casing head, CIW-WF, hil. 13 5/8 3M X 13 3/8 SOW lei _ j agi bottom, w/2- 2" LPOValve, CIW F, 2 1/16 3M FE, �1 �i HWO, AA trim • Monopod Platform 2013 BOP Stack 03/12/2013 Hikury Akuka,UA Rig Floor Bottom of air boot flange 1J\ /II 5'below rig floor 16" 14.72' 9.50 Pipe fil 1 ..I111 II11 ail frittt 3,74' Shaffer 13 5/8 5M III 111.111111 I11 26.25' Shaffer L 2 7/8-5 Variables 2.50' UR135/85M Blind f I!!imp nl III 1/ti, 1.76 111111®11 1 € f ii Mud Cross 1 Whit hli6111135/85MFEX FE w/31/85M EFO w/2 1/16 5M Choke and Kill valves w/Unbolt end III 11 L I'. ill connections for lines -�I�� 13 S ~ - - — - — Dual Cameron Flex rams 2.83' 11111 mini 70' II. IIIIlLlf I11 Drill deck 14.20" UOCD 1911 I:sc• 14.20' 15S/35.FF x115/55MFE rib rffinft]rt 1r) VIII lit 13' 11 5 51 11 1N I Ii1 111 lit 1 wellhead @ 15 00 Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Tuesday, February 25, 2014 11:13 AM To: Schwartz, Guy L(DOA) Cc: Ted Kramer;Juanita Lovett Subject: RE:A-26 RWO( PTD 171-020) Guy You are correct on all counts sir 1. Step 12 is pulling the upper packer which won't work out to well if we don't cut the long string right below the packer 2. Step 9 will need to include testing the BOP's and the new tubing head to 2500psi 3. We definitely will need an SSV as it will no longer be grandfathered 4. Step 25 will need to include a workover MIT We will also need to conduct an initial MIT after 2 weeks of stable injection (between other work overs if the rig is still active) Thanks Dan From: Schwartz, Guy L(DOA) [mailto_guy.schwartz3a3 alaska.gov] Sent: Friday, February 21, 2014 12:01 PM To: Dan Marlowe Subject: FW: A-26 RWO ( PTD 171-020) Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Schwartz, Guy L(DOA) Sent: Wednesday, February 19, 2014 4:17 PM To: Ted Kramer(tkramer©hilcorp.com) Subject: A-26 RWO ( PTD 171-020) Ted, A couple of questions: 1. Do you need to precut the 3 W tubing below the upper packer before pulling the rest of the long string ( cut at about 7360') 2. The new tubing head lower flange needs to be tested to 2500psi . (3000psi connection) 3. Is there a SVS? .... I don't see anything on the tree. 4. need to test and chart the IA(ie packer) before rig moves off...step 25. Guy Schwartz Senior Petroleum Engineer 1 • • Chevron Steve Lambert Union Oil Company of California %11.1 Advising Petroleum Engineer P.O. Box 196247 Anchorage, AK 99519 -6247 %N. Tel 907 263 7658 Fax 907 263 7847 Email salambert @chevron.com January 9, 2006 JAN 1 1 200,S Alaska 011 at 0oe Gongs, Cbtntnission Tom Maunder `~• -- Anchorage Alaska OiI and Gas Conservation Commission 333 W. 7 Ave., Suite #100 Anchorage, AK 99501 -3539 Continuation of Shut -in Status Well No. A -26 Injector Monopod Platform Trading Bay Field . . .._,<, APR 2 I ZO1' Dear Tom, Unocal requests approval under Area Injection Order 12, for the continuation of status as a shut -in injector of non - hazardous Class II fluids for the Monopod Platform Well No. A -26, Injector (Permit #7,1 -) in Trading Bay Field. 1 `Nk-o 'O To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief /relevant well history (below and attached). Well A -26 was completed as a dual string injector in the "C" zone in 1972. The peak injection rate into this well was in excess of 6200 BWPD. The well had a history of fill in the short string caused by back -flow during shut -ins. The fill was removed by circulating mud down the long string and up the short string. The well was treated with a Clay -Sta polymer sand – stabilization treatment to control sand production in December 1976. The treatment was unsuccessful and the well was shut -in for 10 months. In December 1977, injection was resumed. The well was shut -in after 2 months of injection when water break - through occurred in offset B zone producer A -22. A -26 has been idle since that time. Cumulative injection has been 4.5 MM barrels. Depending on the results of future development, it may be c.asirable to return this well to injection. Unocal will seek concurrence from the AOGCC b :fore attempting to return this A -26 to injection. Union OiI Company of California / A Chevron Company http: / /www.chevron.com • • Tom Maunder Alaska Oil and Gas Conservation Commission January 9, 2006 Page 2 Unocal will continue to monitor and record daily tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this request please contact me at 263 -7658 or Larry Greenstein at 263 -7661. Sincerely, i 41/4 Steve Lambert cc: MIT book Well File Union Oil Company of California / A Chevron Company http: / /www.chevron.com • Trading Bay Unit UNOCAL G Well # A -26 Last Completed 11/6/72 RKB to TBG Hngr = 36.40' CASING AND TUBING DETAIL Tree connection: Dual 3" 5,000# SIZE WT GRADE CONN ID TOP BTM. 31_ Tag @ 2004' 13 -3/8" 61 K -55 Butt 12.515 Surf. 1,036' !/29/81 9 -5/8" 47 N -80 & P -110 Butt 8.681 Surf 8,795' Tubing: ' I LS 3 -1/2" 9.2 N -80 Butt. 2.992 0' 7939' SS 3 -1/2" 9.2 N -80 Butt. 2.992 0' 7360' SL Tag @ 6045' 8/29/81 l I 1 JEWELRY DETAIL A 1 1 NO. Depth ID Item I I 1 1 36.75 Cameron DCB Dual 3 -1/2" Tubing hangers, I I ii SHORT STRING 1 ) I I A 6264' Three (3) Baker 3 -1/2" Telescoping Joints, 10.69' long 1 B 7276' 2.75 Otis "XO" Sliding Sleeve C 7343' Baker Model "A -5" Dual Hyd. Pkr D 7358' 2.635 Otis "N" Profile Nipple E 7359' Shear Sub B o btm 7360' o 2 LONG STRING 1 6265' Three (3) Baker 3 -1/2" Telescoping Joints, 10.69' long 2 7305' 2.75 Otis "XO" Sliding Sleeve C >< L ' __ . >< 3 3 7340' Baker Model "A -5" Dual Hyd. Pkr 4 7884' 2.75 Otis "XO" Sliding Sleeve 5 7920' Locator Seal Assy. 11.65' long 6 7920' Baker Model "D" Retainer Production Pkr. D • 1 7 7936' 2.635 Otis "Q" Profile Nipple 8 7938' Collar Guide E btm 7939' I. 2108 Howco DV Stage Collar FISH - C -7 LS Juck Pusher f/ WO 8740' 10/30/72 LS 13.58' Wireline tools 8744' 2/17/73 LS 14.5' Wireline tools 8688' 11/2/73 C -7 FILL LS Tagged 1" OD tools 6045' 8/29/81 = C-7 SS Tagged 1" OD tools 2004' 8/29/81 = - C -7 CP - C -7 PERFORATION DATA Accum. Date 4 Zone Top Btm Amt. SPF Last Opr. Present Condition o C -7 7,502' 7,512' 10' 2 4/24/72 Open 5 C -7 7,538' 7,550' 12' 6 11/2/72 Open �‹ 6 C-7 7,582' 7,600' 18' 4 11/1/72 Open \ C 7 7,660' 7,678' 18' 4 11/1/72 Open 7,678' 7,680' 2' 4/21/72 Cmt sqz'd ■ ■ 7 C -7 7,720' 7,744' 24' 4 11/1/72 Open 47 -5 7,940' 7,970' 30' 2 4/26/72 Open 8 7,970' 7,972' 2' 4/21/72 Cmt sqz'd 50 -3 8,308' 8,320' 12' 2 4/26/72 Open — 47 -5 8,320' 8,322' 2' 4/21/72 Cmt sqz'd Fill tagged on 2/16/74 Cr 51 -6 8,680' 8,698' 18' 2 4/26/72 Open I 4/21/72 Cmt sqz'd Cr - 53 -3 ' = 51 -6 CP DD KB ELEV = 101' PBTD = 8,795' ANGLE thru INTERVAL = 55° A - 26 REVISED: 1/9/2006 DRAWN BY: SLT • . (Unocal I WeII:IA- 261ong I Field:IMonopod I6 -29 -2005 I Pressure (psia) 0 250 500 750 1000 1250 1500 1750 2000 0 500 1000 Pressure- Temperature Profile —_ 1. Pull out of hole 2. Making Stops 1500 — 2000 — - 2500 d 3000 - - G> 2 3500 — - t CD 4000 - 4500 - 5000 -- 5500 -- 6000 — 6500 — — - 7000 50 60 70 80 90 100 110 120 130 Temperature (Deg. F) Pressure 13 3/8 9 5/8 3 1/2 —Temperature • A -26 Well History • • Last Update: 6/29/2005 Date Event Drilled and ran 9 -5/8 ". Perfd & Acidized C -7, 47 -5, 50 -3, 51 -6. Ran prod log. Dual injector, SS - C (C -7). 5/1/72 LS - C (47 -5, 50 -3, 51 -6). 8/1/72 Acidized LS w/15% HCI. Circ fill out of SS. Worked over. Washed perfs w/15% HCI. Ran profile. Reperfed C -7 & tested. Acidized all sands. Dual injector, SS - C (C -7), LS- C(47 -5, 50- 11/1/72 3, 51 -6). 2/1/73 Circ fill out SS, Bail fill out LS. 8/1/74 Circ out fill SS. 11/1/76 Circ fill out SS, treat w /Cla -Sta. SI after water broke through annulus of A -22. Since A -26 just started taking water, it was felt this may be 2/1/78 the cause of the A -22 problem. 5/1/78 Survey showed probable leaks in both tubing strings and in casing at 5,450'. 4/1/86 Proposal to deepen & recomplete failed. 6/29/05 RU on SS. Ran 2.00" GR to 2010' and tagged up. Ran temp survey to 2010'. RU on LS. Ran 2.00" GR to 7400'. Did not tag. Ran gauges for temp survey to 6320' and tagged up. Unable to work deeper. O:\ OOE \OOEFields \Monopod\WeIIs\A-26 \Well History \A26WeIIHistoryJHM 1 of 3 A -26 Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 0 - \ . n date : 1/4/2006 8:00:22 AM S i - operating pressures (surface gauge) Po. ction = 4809 psi. @ 70% nominal casing yield In er , ediate = 264 psi. limited by fracture pressure at shoe Si rfai - = no data available Carr• t Pressure readings Surveillance Thresholds - FE GPR SS = 0 Warning = 150 Alert = 1000 C ■ GPR SS2 = 60 Warning = 375 Alert = 400 1,000 CiGPR S3 = 25 Warning = 375 Alert = 400 C 'GPRE S5 = 0 Warning = 175 Alert = 200 Casing I -tails Size Weight Grade Yield Top Bottom Pooduction ' -gment 9.625 47 N -80 6870.0 39.0 2107.5 Poduction S _collar 9.625 47 N -80 6870.0 2107.5 2109.6 Production S ;ment 9.625 47 N -80 6870.0 2109.6 6714.0 Poduction Se. ment 9.625 47 P -110 9440.0 6714.0 8750.6 Poduction FIG. lar 9.625 8750.6 8752.4 Poduction Seg •ent 9.625 47 P -110 9440.0 8752.4 8792.9 2,000 Poduction Float- oe 9.625 8792.9 8795.0 In ermediate Casi •g 13.375 61 K -55 3090.0 41.0 1038.4 ( sing Parame ers / Assumptions Production casing yi; d © 70% of nominal with fluid weight of 0.433 #/ft In ermediate casing -Id © 45% of nominal with fluid weight of 0.433 #/ft S�rface = no data ava able Frp A 1 cture gradient = O. ../ft I : 507332023000 3,000 P rmit :1710200 rkbook : A -26 Casing P -ssure Analysis ©70 percent 20060104.xls 4,000 0 H II CD 0 5,000 Variable Definitions 6,000 - RP = Reservoir Pressure CYP = Casing Yield Pressure SF = Safety Factor (70% for working annulus; 45% for outer annuli) HP = Internal Fluid Hydraulic Pressure MASP = Maximum allowable surface working pressure Graphical calculation method Inside pressure potential == Outside pressure containment Therefore HP + MASP = RP + (CYP * SF) Rearranging 7,000 MASP = RP + (CYP *SF)_HR - Internal Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft Production CYP @ 70% - Outside Containment for Production casing 8,000 - —MASP (production casing) - Intermediate CYP @ 45% - Outside Containment for Intermediate casing MASP (Intermediate casing) Current Pressure Readings Disclaimers (fine print) Casing yield values taken from published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. 9,000 TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD Graphical Casing Pressure Analysis ver 24a.xls Unocal Corporation 909 West 9~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL ) December 31, 2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Time extension for Monopod A-26 MIT. Dear Tom: We are asking for a time extension on this MIT till December 31, 2002. Monopod A-26 (API# 50-733-20230-00) has been shut-in since 1978 and its MIT is due this year. This well has holes in the tubing and scale in the tubing that limit access and make a regular MIT impossible. Rather than do any diagnostic work on this well, Unocal is planning to redrill the well as part of our 2002 Monopod drilling program (May - Oct 2002). If the redrill is cancelled or postponed we will develop a plan obtain a SI MIT. Therefore we ask that you approve the attached 10-403, if there are any questions please call me at 907-263-7830. Sincerely, Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management RECEIVED DEC, 3 1 Z001 AlakaO l&6asC . Aogcc Monopod A-26 Time extension 12-31-01 .doc JJD ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well Plugging: Time extension X Stimulate: Change approved prograrr Pull tubing: Variance: Perforate: Other: 2. Name of Operate 5. Type of well 6. Datum elevation (DF or KB Union Oil of California IUnocal Development 101.75 RKB/MLLW) feel 3. Address Exploratory 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 9951(` Service: "X Trading Bay Fiel¢ 4. Location of well at surfac( Conductor #3C 8. Well number 1606' N and 563'W from SE corner Sec. 4, T9N, R13W, SlY A-26 At top of productive interve 9. Permit numbe~ 71-20 At effective deptl' 10. APl numbel 50- 733-20230-00 At total deptl' 11. Field/Poe Trading Bay Fiel~ 12. Present well condition summar Total depth: measured 8795' feel Plugs (measured', true vertica 5661' feel Effective depth: measured 8795' feet Junk (measured', true vertica 5661' feet Casing Length Size Cementer Measured deptl' True vertical deptl' Structural Conductm Surface 1,036 13-3/8" 700 sx 1036 1001 I nte rmediatE 8,795 9-5/8" 2650 sx 8795 5661 Production Liner Perforation depth measured See attached diagran true vertica Tubing (size, grade, and measured deptl' See attached diagran Packers and SSSV (type and measured deptl' Baker Model "A-5" Dual Hyd. Pk Baker Model "D" Retainer Prod. Pk 13. Attachement.~ Description summary of proposal X Detailed operations prograrr BOP sketch: ,, Directional Prograrr 14. Estimated date for commencing operatic 15. Status of well classification as 16. If proposal well verbally approve( Oil: Gas: Suspended: Name of approver Date approved Service x 17. I hereby certify that the foregoing is true and correct to the best of my knowled.( c, Signed: Title: Senior Reservoir Enginee Date: 12/20/2001 ~ ~-" ~" - 'v FOR COMMISSION USE ONLY .......... Conditions of approval: Notify Commission so representative may witness JApproval N~/. Plug integrity__ BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 10- tr%~ - Original Signed By Approved by order of the Commissioner Cammy 0echsli Commissioner Date ~/~:~ ~.J 0 c~ RECEIVED Form 10-403 Rev 06/15/88 DEC 3 ! ZOO1 Alal~ Oil & Gas Corns, Commission Anchorage SUBMIT IN TRIPLICATE Trading Bay Unit Well # A-26 Last Completed 11/6/72 8/29/81 RKB to TBG Hngr = 36.40' Tree connection: Dual 3" 5,000# @ 2004' SL Tag @ 6045' 8/29/81 5 IFill tagged on 2/16/74 @ 8688' i SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 9-518" Tubing: LS 3-1/2" SS 3-1/2" 61 47 9.2 9.2 K-55 BuR 12.515 Surf. 1,036' N-80 &P-110 BuR 8.681 Surf 8~95' N-80 BuR. 2.992 0' 7939' N-80 BuR. 2.992 0' 7360' NO' Dept~ 36.75 A 6264' B 7276' C 7343' D 7358' E 7359' btm 7360' I 6265' 2 7305' 3 7340' 4 7884' 5 7920' 6 7920' 7 7936' 8 7938' btm 7939' JEWELRY DETAIL ID Item 2.75 2.635 2.75 2.75 2.635 Cameron DCB Dual 3-1/2" Tubing hangers, SHORT STRING Three (3) Baker 3-1/2" Telescoping Joints, 10.69' long Otis "XO" Sliding Sleeve Baker Model "A-5" Dual Hyd. Pkr Otis "N" Profile Nipple Shear Sub LONG STRING Three (3) Baker 3-1/2" Telescoping Joints, 10.69' long Otis "XO" Sliding Sleeve Baker Model "A-5" Dual Hyd. Pkr Otis "XO" Sliding Sleeve Locator Seal Assy. 11.65' long Baker Model "D" Retainer Production Pkr. Otis "Q" Profile Nipple Collar Guide I, 2108 Howco DV Stage Collar C-7 C-7 C-7 C-7 C-7 47-5 53-~ FISH LS Juck Pusher f/WO 8740' 10/30/72 LS 13.58' Wireline tools 8744' 2/17/73 LS 14.5' Wireline tools 8688' 11/2/73 FILL LS Tagged 1" OD tools 6045' 8/29/81 SS Tagged 1" OD tools 2004' 8/29/81 PERFORATION DATA Accum. Date Zone Top Btm Amt. SPF Last Opr. Present Condition C-7 7,502' 7,512' 10' 2 4/24/72 Open C-7 7,538' 7,550' 12' 6 11/2/72 Open C-7 7,582' 7,600' 18' 4 11/1/72 Open C-7 7,660' 7,678' 18' 4 11/1/72 Open 7,678' 7,680' 2' 4/21/72 Cmt sqz'd C-7 7,720' 7,744' 24' 4 11/1/72 Open 47-5 7,940' 7,970' 30' 2 4/26/72 Open 7,970' 7,972' 2' 4/21/72 Cmt sqz'd 50-3 8,308' 8,320' 12' 2 4/26/72 Open 8,320' 8,322' 2' 4/21/72 Cmt sqz'd 51-6 8,680' 8,698' 18' 2 4/26/72 Open 8,698' 8,700' I 2' , 4/21/72 Cmt sqz'd ~'_ 51-6 KB ELEV = 101' PBTD = 8,795' ANGLE thru INTERVAL = 55° REVISED: 9/26/01 DRAWN BY: SLT Monopod Procedure for MIT on:~26~!,$~:~:in'i:nj~tO~ ~ · 1. Record daily tubing, casing., .and outer casing pressures for a consecutive three day period. 2. Change casing pressure by either increasing or decreasingthe casing annuli by 200 psi. Continue recording daily tubing, casing, and outer casing pressures for an additional, consecutive, four-day period. IWe,, #= A-26" TUbing Pressure.~- " Date LS SS Casing Pressure Outer Casing Pressure ":~'::~' ~ ~ ~ - . Pressures Recorded By: ~t~~/C/~'~ ~~_~C-Ie~ Unocal Corporation Agricultural Products 909 West 9Ih Aw"nut. P.O. Box 196247 Anchorage, Alaska 99519-~247 Telcphoflc (907) 276-7600 UNOCALe .. Janumy 26. ~998 · Blair Wond~H State of Alaska Alaska Oil and Oas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99S01 Re: Approval and Tire.Extension of Monopod Shut-in MIT's D~r Blah': o Thank you for your assistauce last Friday. Itt order to document our conversation and update our w~ files would yo~t pleas~ s/Ipt and date Sc A-SB. ,aud tho A-25 shut-in M1T's for v~tfication that they l~w p~$ed and fax nm a copy at 263-?874. In addition would you please, si~n and fax back a copy oftlxi~ lctter v~'ifyin$ a tlm~ extension' unttl the end of March 1998 for XJnocal to redo the shut-in M1T's ~or u~xe A-12RD2 and ~e A-29 Monopod wells, Senior Reservoir Engineer Pless~ tndicate your approval for 0re timc-e~ension until the end of March 1998 by $1gtling ~d Pdxing a copy of this lettm' to 263-7874, Thanks ag~n for your help in this matt~. Date 1998 JAIX-~'I-~ IU{: IV;Ii J~E~-~t~ iq, ii 17:52 i-lUbUU ("~ORL ~SET ORS OEP Fl-lA flU, ~UI FAX NO, $07{ 374 r, u/-/u,~ P, 05/08 '.; ~l ] I_ Procedumfor MIT q.n.$hut, ln M.o. nopod.!nlec__tor 1. Record daily tubing, casing, and outer casing pressures for a consecutive 10 day period. .... Tubing Pressure Outer casing Pressure .... J _ .~. ._ Jr : ,,,,,, ,,. ,, ,,,,,,. . .. .... Date L$ 8S Casing press?re 13-318" 20" I1.1 _. 'L~3[ I...J_LL IIIIIq.~" ..¥7,/7/97 _ 7.5,, psi 0 psi , 0 Us.[ ......... 50psi 0 psi . 7/8/97 . 75 PSi q psi ..... O psi_.. 50 psi . 0psi 71919_7 .,_ 7;,,5 ps! ,~ ,0 psi:~. ....... ,0, pal _ 5,,,0 psi ...... 0 P~.i., · , · 7110./97 ,L~ 7.5:..p$1 ...... ~ psi 0 psi ..... 50 psi.. 0 psi _.7/11/97_. ,g0 Psi ...... o psi 0 psi ....... 50 ,p.,$1 0 psi ...... .... 7/12/97 ..BO.psi O.~si .... , 0,,,psl ,, !0 psi 0' psi .... 7!13197 90, .psi 0psi ...... 0,, psi ..... !,,~0 PSi ....... '0 psi 7/!4/.97 80 pal 0 psi 0 psi .... ~,0 ps! ....0 psi 71~$/97 80 psi 0 psi ... 0 psi. 50 ps.i .......... 0 PS.! ...... ~. 7!! 6197 .... 80.psi 0 psi ,,0 psi 5,0 psi 0 ps,,!,, Unoca~ AlasKa Resource,, ~Jnocal CorPoration ~09 West 9th Avenue. F.©. Box ~ 95247 Ancnoraoe. AlasKa 99519-6247 'Telephone (907'~ UNOCAL January 23, 1998 Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status and Plans for MIT testing of Cook Inlet Injection Wells Dear Blair: Thank you for your assistance in helping us complete our mechanical integrity testing of water injectors in the Cook Inlet Area. The following is a status of our efforts to date. We also request a time extension for a group of wells listed below to allow us to complete testing work. We request a time extension for completing MIT testing on the following wells until the end of March 1998: Currently shut-in wells Granite Point Field Anna 19-42 Anna 27-42 Anna 46-42 ~--r~;+-" r'3,.,;,.,+ I~1.~+~: ..... tar ....... ~ , ...... ,.., .... ,...~,l 33-14RD Middle Ground Shoal Field Baker #4 Baker #9 Currently injecting wells Tradinq Bay Field Monopod Platform A-8RD2 Wells Needing Repair The shut-in MIT on Bruce Platform Well. # 31-42 indicated a problem with the temporary abandonment which was completed on 10/7/88. We will develop and send to you a procedure for repairing or permanently abandoning this well. An MIT on shut-in Granite Point Platform Well. # 33-14 indicated a mechanical problem with this well. We will develop and send to you a procedure for repairing or permanently abandoning this well. We also want to confirm your receipt and approval of the following shut-in MIT tests. For our records, please sign and return a copy of the following shut-in MIT tests: Baker #8 Baker #12 Monopod A-5R Monopod A-12R2 ~-~.~ Monopod A-26 Monopod A-29 Please indicate your approval of the shut-in tests and the time extension requested by signing and returning a copy of this letter. Thanks again for your help in this matter. Sincerely, e~ff~Smetank~ Reservoir Engineer Agreed to by: Blair Wond~ell Petroleum Engineer AOGCC AUG-19-97 TUE 08:25 UNOCRL RSSET GRS GRP FRX NO, 9072637874 Procedu ,re for MIT on Shut-in ,Monopod Inj ,e, ctor P. 03/06 1. Record daily tubing, casing, and outer casing pressures for a consecutive 10 day period. ....... TU,,,b, ing Pressure .............. ,O,,,,uter Casing pressu,,re Date LS SS Casing Pressure 13-3/8" 20" I II IIIIIII I I III I II I II I III II I 7/7/g7 .75 psi ,0 psi ..... 0 psi ,, 50 ,p,s,,,,! ,, 0 psi 7/8/97 75 psi 0 psi 0 psi ..... 50 psi ., O,,,p,S,! ........... 7/9/9,,7 75 psi 0 ps! ......... 0, psi , 50 psi 0 psi 7/!,0/97..... 75 psi 0,psi 0 psi 50 psi 0 psi ,7,,/,11/97 ,, 90 psi ..... 0 psi .... 0 psi .......... 50 psi 0 p...,.s! ...... 7/12/97 ..... 80 psi 0 psi 0 psi 10 psi 0 psi 7/13/97 90 psi 0 p,.s,i ....... 0 ,,PSi, .. 10 psi 0 psi 7/14/97 80 psi,,, 0 psi O,.psi .... 50 psi ............. 0 psi ...... 7/15/97 80 psi 0 psi ..... 0,psi ,,, 50 psi 0.psi 7/16/97 ,, 80 p, si ,0 psi .... 0 psi 50 psi 0 ps! ~,!G 19 1997 Gas Cor~s. ~;ommis~. ~chOrage r~ 1 IkdPl I I , U,,,, urtuL, HL rMA PIU, ~U/d. uOiulH Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNO .AL t January26,1998. Blair Wondzcll State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Approval and Time-Extension of Monopod Shut-in lVQT's Dear Blair: Thank you for your assistance last Friday. In order to document our conversation and update our well files would you please sign and date the A-SR and tho A-26 shut-in M1T's for verification that they have passed and fax mc a copy at 263-7874. In addition would you ploase sign and fax back a copy of this letter verifying a time extension until the end of March 1998 for Unocal to redo the shut-in MIT's for the A-12RD2 and the A-29 Monopod wells. Christopher Senior Reservoir Engineer Please indicate your approval for the time-extension until the end of March 1998 by signing and foxing a copy of this letter to 263-7874. Thanks again for your help in this matter. A~'ced to by: Blair Wondzell/~ Petroleum Engi~er AOGCC Date Unocal North Amerlc~ Oil & Gas Division ~ Unocal Corporation " P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats ~from a registered surveyor but I hope this will meet your needs. Yours very truly, Ga~S.~us~h ': (~,...~,. Regional Drilling Manager GSB/lew RI .CEIV£b APR 2 199!') al~lS.b ~0il & Gas Cons. commi~ba / CONDUCTOR 1 2 3 4 5 6 7 8 9· lO ll 12 13 14 15 16 17 18 19 20, 21 22 .__~.~_._. 24 25 26 27 28 29 30 31 32 MONOPOD CENTER FROM SOUTHEAST CORNER, sEcTIoN 4, TgN, Y" = 2,523,126 LAT. - 60053' 48.65 "X'' = 218,871 LONG. = 151°34' 43 51 ~,~ "Y" COORD. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,1.13.2 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133.8 2,523,137.6 2,523,138.8 2,523,138.8 2,523,137..2 2,523,132.8 2,523,129.4 2,523,132,0 2,523,128.4 ..2,52.3,2.~4.R ...~ --_ 2,523,133.9 2,523,120.9 2,523,131.4 2,523,118.1 2,523,127.2 2,523,123.6 2,523,120.0 2,523,122.6 2,523,119.2 "X" COORD. 218,880.9 218,883.2 218,883.9 218,883.2 218,881.3 218,876.8 218,873.0 218,869.0 218,864.6 218,861.1 218,858.8 218,558.1 218,858.8 218,860.7 218,865.2 218,869.0 218,873.0 218,877.4 218,875.7 218,878.6 218,870.8 218,873.9 .. 91~. R7~. q 218,867.0 218,878.1 218,863.9 .2!8,875.0 218,865.1 218,868.1 218,871.1 218,863.4 218,866.3 WELL # FSL · , A-28 1621 A-25 1617 A-30 1612 1608 A-27 1605 A-23 .1601 A-21 and RD 1600 A-22 1600 A-14 1601 A-13 1604 A,17 1608 A-8 1612 A-15 1616 A-24 and RD 1620 A-29 1624 A-9 and RD 1625 A-19 1625 A-18 1624 A-11 1619 A-3 1616 A-1 1618 A-7 1615 A-4 1611 A-6 1600 A-32 1607 A-12 and RD 1617 A-20 1604 A-2 1613 A-16 1610 A'26 1606 A-lO 1609 A-5 and RD 1605 1 &2 FEL 554 551 551 551 '553 557 561 565 570 573 576 577 577 574 570 566 562 558 559 556 564 561 "'568 556 571 559 570. 566 563 571 568 lm~rm No. P--4 ~. STATE O~F' ~~ OIL AND GAS CONSERVATION COMMll-rEE 99501 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Water Ini ector SUBMIT IN' DUPLICAT~ 909 West 9th Avenue, Anchorage, Alaska 4. LOCATION OF WELL Conductor 30, 1606'N and 563'W of SE comer. Section 4: TgN, R13W, S. M. AP1 NI/~{ERICAL CODE .~0-133-20230 LEASE DF~iGNA~--ION AN'D SERIAL NO. ADL - 18751 ? IF INDIA~. ALOTTEE OR TRIBE NAME 8. L.~IT FA/%M OR LEASE NAME .... TrnH~n~ Rmv 10. r~-XNr,'~,OOL. OR WmD'C.~'r Trad~n~ Bay ll. SE., T., R~M.. (~OM HO~ o~ SE 1/4 of the ~ 1/4 o~-Sec. 8: TgN, ~ S. H. 1~. P~IT 71-20 13. REPORT TOTAL DEPTlq AT E/qD OF MONTH, CI4_A~NGES IN HOLE SIZE, CASING AND C~LWIENTING JOBS INCLUDING DEPTH SET A/VD VOLU1VIES USED, PERFORATIONS. TESTS A/xrD RESULTS FISHING JOB~ JU/~K IN HOLE AND SIDE-TI~ACKED HOLE A-~D ANY OTHER SIGNIFICANT CI-L~NG~ IN HOL~ CONDITIONS. Commenced operations on TBS A-26 at 12:01 ~,_10/26/72. Operations from 11/1/72 up to completion of TBS A-26 ar~' aS'£ollOWs Reperforated 8508' - 8520' 7722' - 7744' 7666' -7678', 7582' - 7600' and 7538' - 7550". Stimulated reperforated' intervals and ran injec, tion profile. Set wireline permenant packer at 7920'. Ran 5 1/2" tubing, set lnto permenant packer at 7920' and set dt~al hydraulic packer, at. 7540'. Removed BOP equipment and .installed xmas tree. Released rlg at 12:00 Mldn~te, 11/6/72. OEC 8 DtVI,IION Gli OiL *ND ANCHORAGE 14. I hereby th reg NOTE--Report on this form is required for .each calendar ~nth~ regardless of the status of operations, and must N filed in duplicate with the oil and gas aonservatbn commiflee by the 15~ of the suec~4ing mon~, ~le~ otherwise directed. Form P--3 I~EV. 9-30-69 Smbmit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION, COMMrI'I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR ~-EH.~IT-~2' 'for such 'p~o~osaL~.) · , OILw,L,, ["q o,,swE,.L F-I OTHER ~'ater Injector 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue, And~orage ~ Alaska 99501 4. LOCATION OF Wl~.I.L ^ts~r~ce Conductor 30, 1606'N and 563'W of SE conmr. Section 4' TgN, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RT to HLLW 101'. ~ 14. Cher~ Appropriate Box To }ndicale N, ature of NOtice, Re, NOTICE OF INTENTION TO: TEST WATER 8HUT-OFF PULL OB ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE J J ABANDONs REPAIR WELL CHANOE PLANS tother) 5. AP1 NU1W. EglCAL CODE 513-133- 2023f1 6. LEASE DESIGNATION AND SF-,RIAL NO. Am.- 18751 ?. IF IiNrDIA2~I, ~J~O'l-l~tJ~ OB TItlBE NAi~_E UNIT, FA.P,.NI OR LEASE NAME Trading Bay State A-26 (12-9) 10. FLEJ. A) AND POOL, OR WILDCAT Tradin~ Bay 11. SEC., T., 1~.., M.. [BOTTOM HOLE OBJECTIVE) SE 1/4 of the ~ 1/4 of Sec. 8' i 9N, RI3W~ S. ~,'I Ig. PER2vilT NO. 71-20 ~}rt, or Other Da~a ' SUBSEQUENT REPORT OF: WATER SIIUT-0FF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEN'T' (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. · 2. 3. 4. 5. e 7. 8. 9. 10. 11. Moved rig over Trading Bay A-26. Installed xmas tree and tested BPV's. Nippled up BOP's - changed and tested rams in BO?'s. Circulated out fill and circulated hole clean. Washed all perforated intervals w/15% I-{CL. Circulated hole clean and ran profile logs. Injected water for breakdown and re-ran profile logs· Reperforated and acid stimulated plugged intervals. Ran dual tubi2g strings to seperate upper and lower "C" zones· Removed BOP's, installed and tested xnms tree. Rig released and returned to injection service. Rig released 11/6/72 at 12'00 Midnite. DIV!$K)N <3F OIL ~N!2) ~45 ANCHORAGE 16. I hereby ~ SIGSE~ Jim R. '-' ' ---'-- TITLE District Drlg, Supt. DATE November 8, 1972 · (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse S,ide STAT(' OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Fo~m P--3 REV. 9-30~ 9 8tibtnlt "Intentions" in Triplicate & "Sul~equent l'~po~.s" ~ Dupl~te ~" ' 5. AP1 ~C~ CODE SUNDRY NOTIC'ES AND REPORTS ON WELLS (DO not use this fornl for proposals to dr~II or to dec'pen Use "APP]~IC.~,TION 'FOR [~El~,il'l'-'' 'for such 'pro,>!als.) o,, m o,s m l(ater Iniector WELL 2. NA.~IE OF OPERATOR ' Union 0il Co...~mny ~F c~l i fnwnl ~ 3. ADDP~ESS OF OPERATOR 909 West 9th Avenue, ~chorage, Alaska 99501 4.LOCATION OF W~L At ,~ Conductor 30, 1606 'N ~d 563 ' W of SE comer. Section 4- TDN, R13W, S. ~x{. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RT to }.'[LLt~ 101 '. Check Appropriate Box To Indicate Nature of Notice, Re ;~,~! -. 18731 ~. IF II~-DiA.~I, AJ.J.~IWE. E OR TRIBE N.a~;LE 8. UNIT, FAiL'Vt OR LF_.ASE NAME Trnd~ng ~. ~NO. State A-26 (12-9) 10. F!¢--LI~ A~ID POOL, OR WILDCAT Tradin5 ECy 11. SEC., T., R.. 5I.. ~ BOTTOi~I HOLE OBJECTIVE ~ - SE 1/4 of the ~ 1/4 of Sec. 8' T9N ~ R131f~ S. ~,i. 71-20 ~ort, or Other Data NOTICE OF INTENTION TO: ~. . FRACTURK TREAT ]~] MULTIPL~ COMPI.ETE SHOOT OR ACIDIZR ABANDONe REPAIR WRLL CHANG~ PLA.~S ,~1 I , . ~ Other) ~ SUBSEQUENT RRPORT OF: WATER SHUT-orr { ,~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING Xi ABANDO,~MEI~Te (Other) (NOTE: Report results of multiple completion on Well C,mpletion or Reeompletion Report and Log form.) '15. D~:SCR~B£ I'nOPOS£D OR COMPLETED OPERATIONS (Clearly state all pertinent details, and ~ivp pertinent dates, including estimated date of starting an)' Il) 2. 3. 4. $. 6. 7. 8. 9. 10. 11. proposed work. i, Ioved rig over Trading Bay A-26. Installed x~as tree m~d tested BPV's. Nippled up BOP's - changed and tested rams in BOP's. Circulated out fill and circulated hole clean. Washed all perforated intervals w/15% HCL. ~ Circulated hole clean and ran profile logs. Injected water for breakdovm and re-ran .profile logs. Reperforated and acid stimulated plugged intervals. Ran dual tubing strings to seperate upper and lower "C" zones. Removed -P~0P' s, installed and tested xmas tree. Rig released m~d returned to injection service. Rig released 11/6/72 at 12'00 14idnite. .. sm~g/ [1[[;~, R. Ual.lender NOV 0 197'2 ANCHOR,GE District Drlg, Supt, November 8, 1972 TITLE DATE (Th|! space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ~"~ }~°' P-~ ' STATE ~.LASKA OIL AND OAS CONSERVATION COMMITTEE SUBMIT IN DUPLICAT~ MONTHLY REPORT oF DRILLING AND WORKOVER OPERATIONS AP1 NU~iERICAJ~ CODE _~n- 1 _xT..-,n,xn 6. LEASE DF.~iGNATION AND SERIAL -~0. ~Bl. - 18731 T. IF INDIAI~. AI.~T ~1~ O~ TRIBE NA~E 8. L.~IT,F.kRM OR LEASE N.~ME State A-26 (12-93 Trading Bay 11. SK.. T.. R.. M.. (BO~OM o~ SE 1/4 of fl~e N~' 1/4 of ~c. 8' T9N. R151?, S..H, . 1~. P~IT NO. 71-20 TOTAL D~m:~_~H_ AT END OF MONTI-I Ct-IAN'GF~ lhl HOLE SIZE. CASING ~ C~[~N'~NG JOBS INCLUDING DEP~ ~ VOLL~ US~. P~O~TIONS. ~TS ~%~ ~SULTS. FISHING JO~. J~K LN HO~ ~D SIDE-~C~ HO~ ~ O~ SIGNIFIC~ ~G~ ~ HO~ CO~ITIONS. Commenced operations on TBS A-26 at 12:0!_am, 10/26/72. Opened sleeves in long 2 7/8" tubing string above permanent single packer and above dual hydrauli.c packer. Circulated £iltered Inlet water do~ long string and out short string. Installed BPV's. Removed xmas tree. Nippled up BOP's, fMled to test. Replaced 3a~I seal ring. Re-tested to 2500 psi - ok. Unseated packer. Pulled and laid do~m dual 2 7/8" seal lock tubing string. Changed and tested ranm in BOP. Picked up S"x hole DP w/ Tri-State packer picker, bumper sub, jars and 5-6 1/4" drill collars. Found drill at 7696'. Appeared to k.e sand and iron oxide as obtained in previous samples. CircUlated out fill' from 7696' te 7850'. Tilt w/ Tri-State packer picker. Mi21ed over Baker permanent podel "D" packer at 7 850'. Recovered packer w/ exception of junk pusher. RII-I w/ 8 1/2" bit and scraper. Drilled and washed fill -and jm~k from 8710' to 8740'. Circulated hole clean. POI-!. Made up well-stim perforation washing toolS. Ran well-stim wash tool w/5' straddle spacing. Washed ali perforated intervals w/ 15% tlCL. Circulated hole clean. Ran ilowco KTr$ and set above lc~'er "C" zone injection, interval and ran profile legs. ~ NOV 197.2 DIVISION OF OIL AND OAS ANCHORAGE D~str~ct Drl*_ ~mt. ~(oyember 7. ln72 DA'I'~ ,..., ~ - Ill l ~ NOTE--Report on this form ~s required for each calendar month, regardless of the status of :operations, and must be filed in duplicate ~ith the Division of Mines & Minerals by the 15th of the succeeding month, un!ess otherwise directed. l~rm No. P--4 P~, 9~39-~7 STATE O~ ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY RE!PORT OF :D.RILLING AND WORKOVER OPERATIONS w,~ [] o~.,.~ Water ector ~. N~E OF OP~TOR Union Oil Co~y of Califo~ia 9 09 West 9th Avenum ~choraoe Alaska 9950] 4. LOCA~ON OF W~:i.T. .~ Conductor 50- 1606'N ~d 565'W of SE co,er. Section 4: TgN, R15W, S. M. ~ AP1 NLrS~EPdC~kL CODE -~n-133-9.073n 6. LEASE DESIGNATION AN-D S~IAL NO. AF)I, - 1R731 7. IF INDIA]~, ALOk 1 EE OR TRIBE NAME 8. LrNIT,F.~=I~{ OR LEASE NA/VIE m~~ Bay State A-26 (12-~ 10. FI~ ~ND P~L. OR %gILDCA. ~ Trading Ba~ n. sgc., T., ~., M.. -(~OM O~~ SE 1/4 of O~e ~ 1/4 of Sec, 8- TgN~ R13W~ S. M. .- 71-20 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING A/WI) CENIENTING JOBS INCLUDING DEPTH SET ~ VOLUATES USED, PER~OP~ATIONS, TESTS A/XrD RESULTS. FISHING JOE,S, JUNK I/~ HOLE A_ND SIDE-TRACKED HOLE ~ND ANY OTI-IER SIGNIFICA/~T CI-IA/~GES IN HOI~ CONDITIONS. Commenced operations on TBS A-26 at 12:01 am, 10/26/72. Opened sleeves in long' 2 7/8" tubing string above permanent- single" paCkb-r and 'above dual hydraulic packer. Circulated filtered Inlet water down long string and out short string. Installed BPV's. Removed xmas tree. Nippled up BOP's, failed to test. Replaced API seal ring. Re-tested to 2500'!. psi - ok. Unseated packer. Pulled and laid down dual 2 7/8" seal lock tubing string. Changed and tested rams in BOP. Picked up 5"x hole DP w/ Tri-State packer picker, bm. per sub, jars and 5'6 ]:/4" drill collars. Found dr~ll at 7696'. Appeared ,to be san~d aaa iron oxide as obtained in pre~.ious samples. Circulated out fill' frbm 7696 to 7850 . TItt w/ Tri-State packer picker. f4~lled over Baker permanent, podel "D" packer at 7850'. Recovered packer w/ exception of j~u~k 'pusher. RItI w/ 8 1/2' bit and scraper. Drilled and washed fill and j~uuk from 8710~ to 8740'. Circulated hole cle~. t~3I--!. Made up vel. l-stim perforation washing tools. Ran vell-stim wash to°l w/5~ straddle spacing. Washed all perforated intervals w/ 15% IICL. Circulated hole clean. Raa~ Iiowco RTTS and set above lower "C" zone injection interval and ran profile 1.ogs. NOV O t977 ~N GF OtI. AND, GAS ANCHORAG~ with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. STATE O'F ALASKA Form I~E V~. 9-30-6 9 Smbrntt "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 drill or to deepen Use "APPLIC.~.TION 'FOR ~'E~IT-Z-'' 'for such 'p~o~osal~.) · . · . 1, O,L,,.ELL [--] O.S..ELL r'q O~HER Water injec'l;or 2. NADIR OF OPERATOR Union 0il C~any of Cali~ornia 3. ADDRESS OF OPERATOR 909 West gth Avenue, Anchorage, Alaska 4.LOCATION OF WELL 99501 Conductor #50, 1606'N and 565'W of SR corner. Section 4- TPN, R15W, S. Fi. At surface 13. ELEVA'rlONS (Show whether DF, RT, GR, etc. RT to MLLW 101' 14. Cl~eck Appropriate Box To [nd}cate N, ature of N~tice, Re NOTICE OF INTENTION TO: ,,, TEST WATER SHUT-OFF ] I I II__ I] [ PULL OR ALTER CASING ~Jl FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE Jxj ABANDON' REPAIR WELL CHANGE PLANS ~ Other) 5. AP1 N~CAL CODE 50-133-20230 6. LEASE DESIGNATION A_ND SERIAL NO. ADL- 18731 ?. IF INDIAN, A.L,L~'l-i-r.~.; OR TRIBE NA2VLE 8. UNIT, FA_RNi OR LEASE NA1V[E Tradin~ Bay 9. WELL NO. 10. F~-~~, O~Y~T Tradin~ ~v O~E~IVE) SE 1/4 of ~e ~ 1/4 of ~c. 8; TgN. R13~. S. M. 71-20 ~o., or Other Data ' 8UBBEQUENT R~PORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACXDXZING ABANDONMEKT' (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. 1. Move rig over well #26. 2. Remove xmas tree, install and test BOP's. ~. Kill well w/ weighted salt water if required. 4. Pull dual tubing strings and packers. 5. Acid wash w/ 15% ~-EL w/ pressure washer as directed. 6. Clean out. 7. Re-run tubing strings as before. 8 Remove BOP's install tree 9. Return well to injection service. Estimated starting date, .October 24, 1972. OCT 2 197, 16. I hereby cert~t the fore~inL~ true and correct /-~- O~;m R. Call~nder DIVISION OF OIL AND GAS ANCHO~A,O,,~ TITLE Di_~trl ct_ ~r!g. ~_~t. DATE .Oc~x)h~? 20 i 1972 (This space for State office APPROVED BY ~~.' CO.raTIOnS O~ ~'~P~O~'A£, TITLE Chief ?e%roleum Enginee~ See }nstructions On Reverse Side Approved Copy Returned MemOrandum .Union ~il Company of California unl :n June 18, 1973 TO WHOM IT ~Y CONCERN: Due to a mix-up in mailing lists and inconsistency in forms, all repair records and drilling well records since February 21, 1972 are being redone and distributed. You will be receiving copies that you may or may not have already received soon. Please. replace those on file with the new records. JRC/sk Enclosures District Drilling Supt. JUN 2 0 ig73 D!V':;.k.~N ,-.F OiL AND GA5 ANCHORAGE Form 935 (Rev. 7/67) GH[:.,= 1 A PAGE I'.lO ....._l__ ..... '",' ~- WELL NOA-_26__[qQ_ SPUD DATE I,,,AoE Trading Bay State IrlG[,D ........ IradSng_Bay. Monopod Platform CO?,ITltACTOR. WODECO LOCATION_, .F~nduc_l~_J~3Q. 160]~' N.& 563' W. _ rrE_SE~er Sedt .... 4, TgN, R13W, SM P~RMIT NO ..... 71-20 , .SERIAL NO./[D.L-!8731 _ T.D. 8795' T.V.D. 5674' SIZE WEIGHT 13 3/8 , 61# .,, 9, 518 47 · Seco_ndj ;tage,- 8~ · COMP, DATE _] ]._=.6=...7_? RIG NO._ 56 TYPE UNIT__J3i]Me~_L860 El ec. trj_c DRILL PiPE DESCRIPTION 5" 19,5.0# _w 4/_J_~2 IF co~ ELEYATIONS: WATEI[ Di£I~I'II IL T, TO OCEAN FLOOR _ ]74' R.T. TO ,~ILLW 101' (MSt) DEVIATION (B.H.L.) 6305..51 ' ..S 5_5° 5' W' of Surface lq.T. TO DEILL DECK 22.07' COMPANY ENGINEER Mork - Watson - Shell ...... Iq.T. TO PtlODUIS~TION DiZCX~_ 40.82' _ ........................... . ~ .................. ~__~~&~~ ................ CASING & TUBING RECORD ....... THREAD G~ADE DEPTH ~EMA~KS Buttress K-55 1036' Cemented to surface - 500 Sx Perlite S 200 Sx "6" .Buttress N 80-Pll0 8795' First staqe-400 Sx "G" w/4g 6el + 800 Sx "6" w/ _ 4% Gel S 1/2 ft. Perlite/Sx + 500 "5", All D-31, 0 Sx "a" w/4g. ael a 1/2 ft, Perlite/ Sx alg 5-31 + 150 Sx "6" w/lg ~-31 . PEBFOEATIHG ~ECO~D 4-20-.72 8698 8700' 8749 Squeeze #1I Squeezed wi th 200 ~rr~z co,u)tr_to.~{ ....... - ' Sacks Cmt. .t.o 2700 psi 4-21-72.. 8320 - 8322' 8749.' Squeeze #2 Squeezed .with 200 Sacks .Cmt; .t.0.2450 psi 4-21-72. 7970 - 7972' 8749' .Squeeze #3 Squeezed with 200 Sacks Cmt. Teste. d. to 3000 psi- 4-21-72 7678 - 7680' .. 8749' Squeeze #4 Spotted £mt across pe.rfs, Unable to squeeze 4-24-72 7502 - 7512, 8789' Water Inj. 2 HPF Acidized · '-'4-24-72 7538- 7550' 8789' Water Inj. 2 HPF Acidized . -;4225-72'"' 7582 - 7600' '8789' Water Inj.. 2 HPF Acidi'zed ' - '~4-25272' 7660 - 7678.' 8789' Water Inj, ' 2 HPF Acidized " · .:'4_'2'62/727720 7744' . 8789, Water Inj. 2 HPF Afi"idized .. Z4-26-72 79.4_0 ~ 79'70" .. 8789' ' Wate, r-Inj.. 2 HPF Acidized " ' 4-26-72 8308 - 8320' 8789' Water Inj. '2 HPF Acidized '.'.4-26-72 8680 ,- 8698" 8789" Wa..ter Inj'. 12' HPF Acidized ' ....... ii'1'/6/72 Re=perf';~t' w/2 ilpF,. ... " ' .. 3 1/2" Long String ' "7939" ------ · See Tubin,~'Detail ~13.1/2" Shqrt Str.ing -..7360' ....131/2" Dual. Packer -' 7342' " .......... [3 1/2'.' Sinqle Pj_c._k!r -. 7920' _ . --:_ . INITIAL PRODUCTION , , WELL EH_E_kD_A_SSE~ ~ Y _.. TYPE:' Cameron . : . CASING HEAD: 13 3/8" SOW x 12". 3000# "WF" w/2" 5000# flanged Ou]~lets CASING HANGER: Type "CA"-slips & seal assembly - 12" x 9 5/8" with 'R" $eal CASING SPOOL: OCT UO0 9 5/8" 0.D 12" 3000# x 10" 5000# with 2 2 xo...~# flanged Outlets TUBING HEAD:. w/l blind flanqe and one 2"x5000# [:lanqed g'ate valve. ' ' OCT .(one set) U-60 tbg. hangers, 10" x 3 l/2" OD w/3 l/2" buttress box down and TUBING HANGER:3 1/2" 8RD box up w/3" BPV safety grooves~.&.l/4" control line hole.(tappxld_L_ , TUBhNG tlEAD TOP' 10"x5000# flanq'ed w/API rinq groove MASTER VALVES: 3 - 3" 5000# w/ crescent flanges .... 10"x50O0# stud~-d bottom w/3" 'k 3"r~-'5000# studded top. One set CitK!STMASTItEI..;TOP ......... valves, crescent flanged, 3" x 5000~. One dual soli~ block tree ~.~t~ 3"-3" ~ 50~ ~/'~¢es~ ' JUN 2 0 ' ~ ~.. _ . .1 DI ¢:,~I~ I ~ i- ,~. I~ AND ANCHORAOE Trading Bay State ~,a,, r ~ A-26 Trod i nq i LOCATiON._CondNct. or__#3_0__]_O!~6_'.._N. & 5,63 W. ._Qf_~SE ...... Car_ner_~ecti_on 4 T9_N, _ R13W, SM. P~IiMIT NO, 71-20 SERIAl, NO. ADL. 18731 OIL CO. WELl_ F:L(CORD ~' PAGE NO. 1 SPUD DATE4-1-7~ COMP. DATE 5-2-72 CONTI~ACTOR NODECO I~IC; NO. 56 TYPE UNIT .... ~Nell 860~tric D~!LL PiPE DESCRIPTION 5,. 19,50~/4 ~2"IF corm ELEVATIONS: WATER DEFI'iI 73' ~.'T. TO OCEAN FLOOR 174 ' · ' T.V.D. _56Y2~ I.D. 8795 ' H.T. TO MLLW 1 01 DEVIATION (B.H.L.) 6~05,51 S. 55° 5'- W. of'~urface R.T. TO DR[I.,L DEC~ 22.07' 0K COMPAN~ ENGINEER Mork - Watson - Shell R.T. TO PHOI~CTION DEC~ 4~.82,I .... CA~J~IG_a TUBING RECO~D SIZE WEIGHT 12.3/2 9. s/a 61~ 47 6.,.4# 'I'ftREAD GRADE Buttres~ Buttress !Seal-Lock 2 7/_8 K 55 N 80-PllO 'N 80 DEPTH }IEMARKS 1038-'--- See Sheet "D". 87951 See Sheet "D". 'nua 1 ) attached detail PERFOi~ATING RECORD ]DATE I m Iit;ial/IL r.9.". P~rzO~IL ] ......... .P~E~E~T Co~u2~LqN ' 4.'~0272 8698-8700' 8749' Squeeze ¢1 I S_queezed with 200 Sacks CmFto 2700 PSI 4-21:72 8320-8322' 8749' Sqgeeze fi2 ,Squeezed with 200 Sacks Cm~ to 2450 PSI 4-21-72 7970-7972' .., 8749' Squeeze ~3 Squeezed with 2'00 Sacks Cmt. Tested to 300~--- 4z21-72i 7678-7680' 8749' Jqueeze fi4 SpotSed Cmt across Derfs. unable to.soueeze ~-24-7~ 7502-7512' 8789' Water I~j. 2 HPF Acidized " J-24-72 7538-7550' 8789 Water Inj. 2 HPF Acidized ,,, . 4-25-72. 75.82-7600' 8789' Water In.i. 2. HPF Acidized 4-25-72 7660-7678,' · , 8779' Water Inj. 2 HPF Acidized ,, 4-26-72 7720-7744' 8789' Water Inj. ' 2 HPF Acidized 4-26-72 79407~'970ira' ,8789' ' Water Inj. '2 HPF Acidized ~] IF ll' Ih 4-26-72 8308-8320' 8789',,,,, Water Inj.. '1 2 IiPF Acidized ~< ~ ~ ~ 4--'2m6--72m 8680--8698' 8789' Water Inj.12 HPF Acidized' J~ ..... ~ .m ' . JUIq ~ kJ I~(m -- "' . .... ............ , , · ~ ~m ~F"'%~. 'i ~ .... . " .- · , ., INITIAL PRODUCTIO_~T --- . . NET O ~ L I CUT GR.~.V.I C.P.. T.P7'i' '~...~'Ok'Z ~.kq? GOR -]" , ~F&I~ , .. ,. . W ELL ~E~_~RzI ~ Y TYPE: Cameron ..... ' , CASING HEAD:, 13 '3/8" SOW x 12"' 3000# "WF" with 2" 5000# Flanqed Outlets CASING.HANGER:.. Type "CA" Slips and Seal A~sembly - 12" x 9 5/8"'with 'R' Seal CASING SPOOL:.. TUBING HEAD: 12" 3000#-x 10" 30bO# DCB with two 2" 5000# ~tudded Outlets TUBING ItANGER: DCB'2 7/8" x 2 7/8" EUE 8RD Top and Bottom TUBING IIEAD TOP: 10" 3000# Flanqe MASTER VALVES: 3000// Single String Block Leg Type With Bottom F1...a..n~ge 10" CHRISTMAS 'FF~ICE TOP CONN.:. EUE 8 RD . i CONTRACTOR .~,~ DII RIG NO, '~ ~ ~," - - RECORD OIL COMPANY TOOL PUSHER LEASE/WELL NO. COUNTY R,G MAKE ~'::'.,,~..:,,_7,',~.. t-._ E~..o ~ S.EET / MODEL RECORD NO.. NO ..... NO. PUMP ~,/,~r'"~,,,/' ~- ' ' 4~ MODEL ,'~,,, -,- ~/'~"-' MAKE TOO,. # r~ JOINTS: MAKE SIZE/TYPE.. O.D. MAKE INTER. ................... III)~,.IT. I. I,,~. UKILL [..ULLAKb: NU, , (.}.D, I.D. LENGTH I JETS.32ND BIT I DEPTH FOOT. VERT. PUMP NO. I' NO. 2 MUD DULL COND. REMARKS ACCUM. WT. SIZE MAKE TYPE , HOURS HOURS lO00 RPM ! Z 3 SER. NO, OUT AGE LB. DEV. PRESS. SPM LIN.SPM LIN. WT. VIS. T B G (FAILURE. MUD, ETC.) '- ,~ i /O.S~c~ /~ /~/ lq ;2~7/:3.1 5~7~2~.5' I:~q~ .~ ..~:~,~Z: ~-~?' .~.3~c &4'~ &'~,ff-b~-~ ~' ~t:.S-'e. Z, _F ~'~/~ r /~yq - : I I I I I I' lUl ~ DdllingTooi~ Division II II I I II REED REPRESENTATIVE, PHONE RO,Box2119 HoustonTexas77001 G~ MUFU'HY ~DUS11~I~ F,-403 IIII I I1[I II CONTRACTOR OIL COMPANY TOOL PUSHER jl~ RECORD COUNTY, STATE DR ~L~/~/~I~ DR ,,~"',Z,-,,'I"(,~,,f~I',,,~ DR ~/~I~EZ~I~ SEC./T'SHIP/ .,G .AKE S.EET TOOL & MODEL RECORD NO. NO. JOINTS: MAKE. SIZE/TYPE O.D. PUMP "0'" ' K ~ ' ~ "O" ~I Imml N~~~ ~ ' // ~ D sPUD D*T~ I~ --/--~ UNDER' ' ~'--'SURF' ' ' ~. '='LJ~'' 7~... DRILL COLLARS: NO' O'D' I'D' LENGTH' NO, 2 PUMP ti mi MAKE & MODEL. INTER. ,T. D. DRILL COLLARS: NO. O.D I D --.LENGTH. RN~)N. J ACCUM. WT. VERT. PUMP NO. I NO. Z MUD DULL coND. REMARKS SIZE MAKE TYPE JETS.32ND BIT, DEPTH FOOT- HOURS I000 RPM DEV. PRESS. (FAILURE. MUD. ETC.) · I 2 3 SER. NO. OUT AGE HOURS LB. SPM LIN. SPMi LIN. WT. ViS. T B G - - -/~,~]zj - Iq 141"c. ~z:)G lq !~ I~ S~ 7~q ~7~ 7~ ~ ~ I1~ ~ ~~ ~ &~ 7~ ~ ~ ~ ~ ...... .... , ....... ........... ............ I i i , ......... I I .... i I I REED REPRESENTATIVE · PHONE G,~ MUlrU~ INIX~STI~ F,,,403 Reed DfillingTools Division iii ii i i i i i RO.Box 2119 Houston Texas77001 iii i i iii i _ iii i ii i ii i i · . MUD I~ECORD PAGE NO 2 L}.iASI,i._S tate WEf,1, NO. A-26 FIIg[,D Tradinq Bay DlS'rRIBUTOI(__Magcobar DATF. I DI~PTII ! ! . . Pt~._~ SALT __~O_J_L__ SAND SOLIDS 4,-,1-72, 620 __76 54 14 1F).5 20M - 1 15 , ,, 2 1.048 .7.6 _ 54 14 10.5 .. 20M -, . ..1 [ I!5 . 3 10.48,. 77 . 53 8 lO 19M - 1 14'",. I(~eninq.,hole to 17 1/2" 'l ' -- ' 4 [I I 1888 80 54- 15 10.5 ._20M - 2 14 5 , 2955 78. 54 16 ll 1SM -. 2 15 , . 6 37 58 77 58 9 10 18M 5, 1 . 5 14 ......... 7 4510 78 53 9 10.5 18M 4 1 13 8 5132 79 54 10 10.5 17M 4 1 ,. 15 , 9 5541 78 45 10 11 16H 4 1 13 m mm 10 . 5851 80 .45 10. -10.5 18M 4 1 15 i, , 11 6581 .77 60 10 l0 1SM' 4 1 12 12 7024 79 48 10 10 1SM 4 1 13 13 7578 79 50 8 10. .. 26M 4 1 ~ 15 14 80_65 79 50 ., 8 10, 26M 4 1 14 ...... 15, 8486 80 54 9 10 24,M, 4 1 1 5 ,,, 16 8725 79 60 10 10.5 24M 4 1 1,5 , , 17 8795 79 55 i 8.5 10 2514 4 1 14 , 18 8795 79 55 8.5 l0 25M 4 1 14 Ran 9 ,5/8,", casing 19 " 79 55 8.5 I10 16M 4 1 14 20 " 80 54 11 ll 16M 4., 2 1-5 21 " 80 48 14 ll 18M 4 2 15 22 " 80 48 15 11 17M 3 2 14 .23, " 78 55 20 ll 20M 2 1 12 Cha..~n3ed to'salt water 24 " 70 Filtered i~let water 25 " " " !' , 27 " " " " " 29 " " " " " 30 " 63 " " , " ,, 5-1-72 " " " , " II II II II II - · __ .... , ,., _ .I , ,. ., ..... . ,, · , , . , . , , , . , · , .. · ,. · .. ,,. · , , . ~ , ......... · ., , · UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO._ 3 LEASE Trading Bay State WELL NO., A-26 FIELD , Trading Bay DATE E.T.D. 4-1-72 6 10 11 12 13 14 15 16 17 620' 1048' 1048' 1888' 2955' 3758' 4510' 5132' 5541 ' '5851 ' 6581' 7024' 7578' 8065' 8486 8725' 8795' DE:TAILS OF OPERATIONS, DESCRIPTIONS &: RESULTS Skidded Rig over conductor #30. Tagged bottom of conductor at 178'. Spudded well - 10:00 A.M., 4-1-72. Drilled 12 1/4" hole to 300'. Dyna-dril led and surveyed to 620'. Dyna-drilled and surveyed to 680'. Drilled 12 1/4" hole and surveyed to 1048'. Opened 12 1/4" hole to 17 1/2" to 963'. Continued openihg 12 1/4" hole to 17 1/2" to 1048'. Circulated and conditioned hole to run 13 3/8" casing. Ran 26 joints (1038') of 13 3/8" 61# K-55 buttress casing with shoe at 1036', and float collar at 996'. Cemented with 500 sacks Class "G" cement premixed with 1/2 cu. ft. perlite per sack, 4% bentonite, 1% CFR-2 followed by 200 sacks "G" with 1% CFR-2 and 3% CaC12. Good circulation with cement returns to surface. Bumped plug with 1000 psi, float held. CIP 9:20 A. M. 4-3-72. Broke out riser system, cut casing hnd welded casinghead spool. Instal led BOPE. Finished installing BOPE. Mixed and poured 15 sacks Class "G" cement around 13 3/8" casing, where cement had fallen away. Tested blind rams, choke and kill lines, etc. to 2500 psi. RIH with 12 1/4" bit. Tested pipe rams and hydril with 1000 psi~ OK'. Drilled plug, cement and sho~/?C to 1048'. Drilled and surveyed 12 1/4" hole from 1048' to 1888'. POH. Layed down 26 joints of drill pipe. Picked up packed hole dril- ling assembly. RIH with bit //4. Reamed tight hole at 1200'. Reamed and washed 1600' to bottom. D. & S. 12 1/4" hole from 1888' to 2955'. POH to change bit. Hole very tight. Drilled and surveyed-12 1/4" hole 2955' - 3758'. Drilled and surveyed'12 l/4" hole 3758' - 3977'. B, it trip - hole condi- tion good. Drilled and surveyed 12 1/4" hqle 3977 to 4510'. Drilled and surveyed 12 1/4" hole 45'10' to 5132'. Drilled and surveyed 12 1/4" hole 5132' to 5441'. POOH' to pick up Dyna- drill to turn direction to the left. RIH with Dyna-drill and bit #9. , Dyna-drilled and surveyed 12 1/4" hole 5441' - 5541'. Dyna-drill. ed and surveyed 12 1/4" hole 5541' - 5591'. POOH laid down Dyna-drill. RIH with bit #10. Drilled and surveyed 12 1/4" hole from 5591' to 5851'. Drilled 12..1/4" hole 5861' to 5851'. Tested BOPE. Drilled and surveyed 6581' - 7024'. Drilled, trip and survey 7024' - 7578'. Drilled 7578' - 8065'. Drilled 8065' - 8486'. Checked BOPE. Drilled 8486' - 8725'. Circulated 1'/2 hour pulled 10 stands. Ran back to bottom at 8725'. CirculAted and conditioned mud for logs. POOH. RU and ran Schlumberger DIL log from 8733 W.L.M. to 13 3/8" casing. Ran Schlumberger F.D.C. - SNP logs from 8733 W.L.M. to 13 3/8" casing. RD Schlumberger. RI to 4570. Circulated 1/2 hour. Ran to 8675, cir- culated and reamed to 8725'. Drilled 8725' - 8795' and circulated one hour. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D LEASE Tradinq Bay State ~VELL NO.. A-26 . FIELD Trading .Bay DATE 4-18-72 19 20 21 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8795' 8749': 8749' 8749' Circulate at 8795'. Made short trip. Reamed 'out of hole from 8110' to 7940'. Surveyed. POOH to run casing. RU and ran ,53 joints of 9 5/8" 47# N-80 buttress casing. Howco float shoe at 8795 , float collar at 8751', self fill collar at 8749', and DV cementing stage collar at 2107'. Circulated before cementing. 9 5/8" Casing Detail Bo t tom Top Len.g th __J ts 8795.00 8Z92.90 2.10 8792.90 8752.46 40.44 8752.46 8750.66 1.80 8750.'66 8748.58 2.08 8748.58 6713.98 2034.60 52 6713.98 2109.65 4604.33 ll7 2109.65 2107.50 2.15 -~'.~-50 - 39. O0 2068.50 52 39.00 -0- 39.0.0 9 5/8" Howco Float Shoe 9 5/8" 47# PllO buttress casing 9 5/8" Howco Float Collar 9 5/8" l~owco Self Fill Diff. Fillup Collar 9 5/8" 47# PllO buttress casing 9 5/8" 47# N-80 buttress casing 9 5/8" Howco DV Stage Collar 9 '5/8" 47# N-80 buttress casing Elevation 222 Total 9.70' Cut Off Circulated. Cemented bottom stage with 400 sacks Class "G" cement mixed with 548 cu. ft. gel water, plus 800 sacks "G" with gel (4%) and 1/2 cu. ft. perlite per sack added and 500 sacks "G" with 1% D-31. First stage pr6ceded by-mud sweep. Displace with 3599 cu. ft. mud. Bumped plug. CIP 3:30 A. M. 4-'19-72.(_~-O_~_pened DV, circulal~ed-~. Took on cement from boat. Cemented second stage w~-~-h~--8'l.rJ~T~E!~-~'-' cement with 1/2 cu. ft. perlite/sack, 4% gel and 1% D-31 ~dded,-~61.1owed by 150 sacks Class "G" cement with. 1% D-3]. Perlite mixed .to 96#/~cu. ft. slurry and neat mixed to ll6#/cu, ft. slurry. Displaced. Bumped plug. CIP at 8:25' A. M. 4-19-72. Approximately 370 cu~_ft, cement to surface. Removed riser. Landed'9 5/8" in Cameron "CA" slips. Installed Cameron 12" 3000# x 10" 3000# tubing head. Tested tubing head to 3000#. OK. Installed riser, BOPE, 'flow line, etc..Tested BOPE choke and kill lines, riser to 2200 psi. OK. Made up clean out drilling assembly. RIH. Drilled and tested D.V. tool at 2107. Cleaned out to float collar at 8749'. Circulated clean. RU Dresser- Atlas. RIH with Howco RTTS. Hung RTTS at 8537'. RU Dresser-Atlas and RI to .p..erforate 4 hpf at 8698' - 8700' with thru tubing guns. Perforated 4 hpf 8698" - 8700" {~lith Dresser-Atlas'. Set Rtts at 8537'. Brokedown perfs with 3500 psi. no rate. Spotted caustic water across perfs. Brokedown with 2800 psi. Established rate of 15 CFM at 2700 psi.' Pumped 50 cu. ft. water ahead, 200 sacks (228 cu. ft.) Class "G" cement with 1% D-31 added and 20 cu. ft. of water behind. Displaced with 553 cu. ft. mud. Closed tool. Squeezed with addi. tional 319 cu. ft. mud to a standing press of 2700 psi. Bled off press and Cement flowed back. Repressed to 2700 psi 3 times. Press held third time. Did not flow back. CIP 5:00 A. M. 4-22-72. Total time 1 hour 20 minutes. Released RTTS. Reversed clean. Pulled to'8131. First squeeze left theoretically 25 cu. ft. slurry in the casing. RU Dresser- Atlas and perforated 4 HPF 8320' - 8322' for sqz #2. Brokedown with 2700 psi. Pump-in rate 2 dfm at 2800 psi. Pumped 100 cu. ft. water ahead, 200 sacks Class "G" with 1% D-31 and 20 cu. ft. water behind. Displaced with 463 cu. ft. mud. Closed tool. Squeezed with 364 cu. ft. additional mud to a standing press of 2450 psi. Total time 1 hour and 45 minutes. CIP 11:30 A. M. 4-22-72. Reversed clean. Pulled to 7820'. Left 43 cu. ft. slurry in casing. RU Dresser-Atlas and perfd 4 hpf 7970' - 7972' for sqz #3. Brokedown at 2000 psi. Pump in rate UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE: NO LEASE Trading Bay State . . Vv~gLL NO. A-26 FIELD Trading .Bay DATE 4-21-72 Cont. E.T.D. 8749' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6 cfm at 1800 psi. Pumped 100 cu. ft. of water, 200 sacks "G", 20 cu. ft. of water, 432 cu. ft. mud. Closed tool. Squeezed with total 822 cu. ft. mud but obtained no build up in pressure. Over displaced 40 cu. ft. Reversed clean. Attempted second squeeze. Could not get breakdown to 3200 psi. Pulled to 7508'. RU Dresser-Atlas. Perfd 4 hpf from 7678' to 7680' for sqz #4. Pumped 100 cu. ft. water with caustic (2sx) and spotted across perfs, after unable to breakdown with 3400 psi. Pul- led up to breakdown perfs. ( Continued - See Page 6) UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO LEASE- Trading Bay State SVELL NO. A-26 FIELD Tradinq Bay DATE E.T.D. DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS 4-22-72 23 24 25 26 8749' 8789' 8789' 8789' 8789' Brokedown perfs with 3200 psi. Rate 2 cfm at '2800 psi. Pumped 100 cu. ft. water, 342 cu. ft. (300 sacks) Class "G" cement slurry, 20 cu. ft. water and 287 cu. ft. mud. Closed tool. Press increased sharply to 3700 psi, varied from 3400 - 3700 psi for a few minutes, then remained constant at 3800 psi with a rate of 2 cfm. One hour and 50 minutes, from beginning of job the pressure increased to 4300 psi. The squeeze was stopped and attempt was made to reverse circulation. Could not 'circulate either way, after 'release RTTS. Pulled string wet. Layed cmt joints down. PU drilling assembly and RIH. Found cement stringers at 7441'. Drilled out Cement 'to 8700'. Broke coupling on rotary shaft. Repaired coupling. CO to 8789'. Circulate hole clean. POll. RU Dresser-Atlas. Ran CBL-GR log from 8789' - 7250'. POH. RD Dresser-Atlas. RIH with Howco RTTS to 8789' Displaced mud with filtered Inlet water. Weighted .Inlet water to 7~#/cu. ft. Pulled RTTS t9 7450', broke ¢_p~.~_perfs with 1800 psi. Injected 5 CFM at 2250 psi. 'R~T-~'~-'~;-o-'~'~' an~]---te~-~e~l--'t'o"de'termine if perfs below were holding. Tested to 2250 psi. OK. Pull-ed and set RTTS at 7449'. Opened tool. Rigged Dowell. Pumped 500 gallons 2 1/2% HCL, 750 gals mud acid and 400 gallons 2 1/2% HCL and 72 bbls. of water. Closed tool. Pumped 2 cfm at 2200 psi until HCL reached perfs and press decreased. Holding 2200 psi, the. rate increased to 4 cfm. Later it increased to 14 cfm when mud aCid hi't perfs and 16 cfm before last HCL was past perfs. Washed with 150 bbls. filtered Inlet water with final rate of 12 cfm (3100 BPD).- Rigged Dresser and perfd 2 hpf 7538' - 7550'. ~9 Completed perforation, rigged down Dresser-Atlas. Set RTTS at 7523. Rigged up Dowell. Opened RTTS, and pumped 480 gallo.ns 2 1/2% HCL, 900 gallons mud acid, 480 gallons 2 1/2% HCL and 400 cu. ft. water. Closed tOQ] and began injecting at 1 cu. fit./min. Breakdown was taken at 2100 psi and rate established at'2 cfm at 2200 psi. With 800 psi on annulus while pumping, communication was observed. Annulus pressure increased to 2000 psi while trying to inject acid into interval 7539' - 7550'. Pumped 180 bbls. filtered Inlet water at 2000 psi at 3 cfm. 'Rigged Dresser-Atlas and perfd 7582' - 7600'. Tested R~TS to 2100 psi with packer at 7667'. Moved packer to 7574', unable to breakdown at 2100 psi. Spot 10 bbls. mud acid across perfs. Set packer at 7574'. Brokedown with 2000 psi. Rate 3 cfm. Maintained 1500 psi on annulus thru breakdown. Press increased to 1900 psi (communication). Dis- placed the 10 bbls. acid at 4 1/2 cfm with 1800 psi. Mud acid to perfs press gradually dropped. Mud acid out to 1050 psi. Rate increased to 15 cfm. I'nject 270 bbls. filtered Inlet water at 1050 psi, 15 cfm. ~RiCg_ed~Dres. ser-A~d perfd' 7660' - 7678". Set RTTS at 7698'. Test to 2i'0-0 ps~. ~ Spot l0 bbls. mud acid across perfs 7660' - 7678'. Set RTTS at 7636'. Brokedown at 1900 psi 2 cfm. Pumped 720 gallons 2 1/2% HCL, 930 gallons mud acid' and 720 gallons 2 1/2% HCL. Displaced to tool and closed tool. .Displaced at 1900 psi at 11 cu. ft. per minute. Broke psi when mud acid hit perfs, 650 psi 13 cfm. Injected 270 bbls. filtered inlet water at 650 psi at 2 1/2 bbls. per minute. Rigged Dresser.-Atlas and-perfd 7720' ' 7744'. Spot 10 bbls. mud acid across perfs. Set RTTS at 7698'. Close tool. Brokedown at 1500 psi, 12 cfm. Displaced acid open tool. Pump 900 gallons 2 1/2% HCL, 1380 gallons mud acid, 900 gallons 2 1/2% HCL. Displaced to tool and closed tool when acid to tool. Broke back to 700 psi at 2 1/'2 bpm. Displaced acid with 180 bbls. Inlet water at 3 bpm. Rigged Dresser-Atlas. Perfd 2 hpf 7940' - 7970'. Spot 10 bbls mud acid across perfs. Set RTTS at 7916'. Brokedown at 1900 psi, 11 cfm. Displaced acid and opened tool. Pump 1200 gallons 2 1/2% HCL. Displaced UNION OIL CO. OF CALIFORNIA DRILLING RECORD S H EET D PAGE NO LEASE~_. Trading Bay State. __ WELL NO., A-26 FIELD Tradi nq Bay DATE 4-26-72 Cont. 27 28 29 5-1-72 E. T. D. 8789' 8789' 8789' 8789:' 8789' '8789' 8747'ETD DETAILS OF OPERATIONS, DESCRIPTIONS 8: RESULTS to tool and closed tool. Pumped acid to perfs. Broke back to 1400 psi at 12 cfm. Displaced acid with 450 bbls. filtered Inlet water at 1400 psi at 3 bpm. Rigged Dresser-Atlas. Perfd 2 hpf 8308' - 8320'. Spot l0 bbls. mud acid across perfs. Set RTTS at 8289'. Brokedown 1850 psi, 5. cfm Pump 480 gallons 2 1/2% HCL, 800 gallons mud acid, 480 gallons 2 1/2~ HCL~ Displace to tool. pump acid away at 1800 psi at 12 cfm. No break in pressure. Displace with 140 bbls. Inlet water at 1800 psi at 7 to 12 cfm. RU Dresser=Atlas. Perfd 2 hpf 8680' - 8698' Spot 5 bbls mud acid across perfs. Set RTTS at 8660'. Brokedown at 1800 psi 8 cfm. Pumped 720 gallons 2 1/2% HCL, 1100 gallons mud acid, 720 gallons HCL. DisPlace acid to tool. Closed tool. Displaced acid to formation at 1800' psi, 8 cfm. No press drop. Pumped 270 bbls. filtered Inlet water, 1800 to 2000 psi at 2 1/2 bbls. per min. Set RTTS at 7853'. Injected with platform injection system at 1450 psi at 5000 bbls per day. Ran spinner and tracer log. Pull RTTS to 7391'. Established rate at 8400 bbls per day, 2050 psi. Ran GO-Int'l profile logs. Ran RTTS tool to 7671' and changed to filtered Inlet water. POOH'with RTTS. Ran wireline junk. Basket to 8000'. Ran Brown production, packer (wireline) to 7850' and set. RU and ran dual 2 7/8" tubing. Unable to stab into Brown packer. POOH with dual string 2.7/8" ,tubing. RI with seal assembly on 5" drill pipe and stabbed into wireline packer at 7850'. Moved down hole. Pres- sure to 1500 psi. Attempted to pull out of packer. Packer moved up hole - pushed Brown packer down hole to 8747' ETD. Pulled out. Made up and spaced out single Hydraulic Guiberson Packer at 7875' and dual Guiberson Hydraulic Packer at 7441', on 2 7/8" tubing. Ran plug in short, string. Set packer at 7i441. Pulled plug up hole. Test packer to 1000 psi. Press dropped to' 500 'psi and circulated. Set plug in XO sleeve 30 feet above packer. Tested tubing to 3500 psi, OK. Pulled tubing. Slips (hold down) on packer worn out. Made up Baker permanent production packer and ran on drill pipe. Set at 7850' and pulled out of hole with setting tool. RI with seal assembly on 5" drill pipe with 300 feet 2 7/8" tubing above seal assembly. Stabbed into packer and injected at 2000 psi 5 minutes. OK. PO of packer with 1000 psi on drill pipe. Packer did not follow up. Tagged packer at 7850. POll with drill pipe. Ran dual tubing strings With Baker seal assembly on dual Otis hydraulic packer. Stabbed into Bakei~ packer at 7850' with Otis dual packer at 6515'. Tested Baker packer, OK. Spaced up and .landed tubing set plug in short string. .Pumped to 1200 psi. Set dual packer at 6515'. Pumped to 2000 psi, OK. Pumped to 2400 psi. Short string stabbed and disengaged. Released dual packer and POOH. Threaded and locked S.S. into dual hydraulic packer. Ran and landed tubing with seal assembly stabbed into Baker packer at 7850', Otis dual packer at 6515', long string expansion joints at 5450' and short string expansion joints at 5411'. Tested bottom packer with 1500 psi, OK. Set dual packer at 6515' and tested with 1500 psi, OK. (Test on Annulus). Removed riser. Installed and tested xmas tree. Test OK. " RIG RELEASED to move to A-23 at 6:00 P. M. 5-2-72. LEASE Trading Bay State NO, A- 6 FIELD Trading Bay Field. ETD DF~TA. ILS OF OP._E~R/NT_!OItS, DESCRIPTIQi.!.S..f~ RES. ULTS 13 3/8" CASING DETAIL 13 3/8" tlowco Guide Shoe 13 3/8" 61# K-SS Buttress Csg. 1 13 3/8" Howco Float Collar 13 3/8" 61# K-55 Buttress Csg. 25 13 3/8" Cameron Csg. }~nger Landed Below Zero BOTTOM TOP 2.00 1038.43 1036.43 40.93 1036.43 995.50 1.75 995.50 993.75 950.60 993.75 43.15 2.15 43.15 41.00 41.00 41.00 .0- INILLL I CORD PAC E ilo, Trading Bay State ¥iELL l'10, A-26 FIELD Trading Bay Field DETAILS_OF OPERATIPlIS, DtZSCRIPTI~'.IS ~ RE..EU_L]LS TUBING DETAIL SHORT STRING 2 5/8" Otis Shear Sub 2 5/8" Otis "N" Nipple 2 5/8" 8rd to 2 7/$" Seallock Combination Coupling 2 7/8" 6.4# N-80 Seallock Pup Jr. 2 7/8" 'Seallock to 3 1/2" 8rd X-over 9 5/8" x 5 1/2" x 5 1/2" Otis ROH Hydraulic pkr. 5 1/2" 8rd to 2 7/8" Seallock X-over 2 7/8" 6.4# N-80 Seallock Pup Jr. 2 7/8" 6.4# N-80 Seallock tbg. 2 7/8" Seallock to 2 7/8" 8rd X-over 2 7/8" Otis XO sleeve 2 7/8" 8rd to 2 7/8" Seallock Combinat ion Coupling 2 7/8" 6.4# N-80 Seallock Tbg. 2 7/8" Seallock to 2 7/8" 8rd X-over 2 7/8" Telescoping Jts. 2 7/8" 8rd to 2 7./8" Seallock X-over 2 7/8" 6.4# N-80 Seallock Tbg. 2 7/8" 6.4# N-80 Seallock Pup Jr. 2 7/8" 6.4# N-80 Seallock Pup Jr. 2 7/8" 6;4# N-80 Seallock Pup Jt. 2 7/8" 6.4# N-80 Seallock Pup Jr. Tubing Hanger Landed Below Zero JTS. LENGTH BOTTOm1 TOP .50 6530.64 6530.14 1.02 6530.14 6529.12 174 .60 6529.12 6528.52 5.49 6538.52 6525.03 .85 6'525.03 6524.18 8.90 6524.18 6515.28 1.15 6515.28 6514.13 6.58 6514.13 1 50.76 6507.55 6507.55 6476.79 1.14 6476.79 6475.65 2.71 6475.65 6472.94 .60 6472.94 32 1044.63 6472.34 6472.34 5427.71 1.14 5411.57 5410.45 5557.15 5410.45 55.30 5.10 55.50 50.20 5.10 50.20 47.10 5'.10 47.10 44.00 8.00 44.00 56.00 1.00 56.00 55.00 55.00 35.00 -0- 1.14 5427.71 5427.57 15.00 5426.57 5411.57 OIL COt PAtFY' UF CAI_IFOt ilI£ 't:LL kf. COI D PAGE 10 LEASE Trading Bay State WELL N0, A-26 FIELD Trading Bay Field , DATE ~ O SE~TAILS OF O?E_R_AZ/L)!i$,.. DF:SCRIPTIO!'..!S &JqESULTo llJBING DETAIL LONG STRING 2 3/8" Guide Shoe 2 3/8" Otis "N" Nippple 2 7/8" 8rd to 2 3/8" 8rd Combination Coupling. 2 7/8" 6.4# N-80 8rd Pup Jr. 2 7/8" 8rd to 2 7/8".Seallock X,over 2 7/8" 6.4# N-80 SeallockTbg. 1 2 7/8" Seallock to 2 7/8" 8rd. X-over 2 7/8" Otis "XO" Sleeve 2 7/8" 8rd to 2 7/8" Seallock Combination Coupling 2 7/8" 6.4# N-80 SeallockTbg. 41 2'7/8" Seallock to 3 1/2" 8rd X-over 9 S/8"x 3 1/2" Otis ROH Hydraulic Packer 3 1/2" 8rd to 2 7/8" Seallock X-over 2 7/8" 6.4# N-80 Seallock Pup Jr. 2 7/8" Seallock to 2 7/8" 8rd. X-over 2 7/8" Otis "XO" Sleeve 2 7/8" 8rd to 2 7/8" Seallock Combination Coupling 2 7/8" 6.4# N-80 SeallockTbg. 33 2 7/8" Seallock to 2 7/8" 8rd X-over. 2 7/8" Telescoping Hts. 2 7/8" 8rd to 2 7/8" Seallock X-over. 2'7/8" 6.4# N-80 SeallockTbg.- 174 2 7/8" 6.4# N-80 Seallock Pup Jr. 2 7/8" 6.4# N-80 Seallock Pup Jr. 2 7/8" 6.4# N-80 Seallock Pup at. Tubing l.~nger Landed Below Zero . .45 7863.97 7863.52 1.02 7863.52 7862.50 .60 7862.50 7861.90 3.37 7861.90 7858.53 8.65 7858.55 7849.88 1.80 7849.88 7848.08 1.14 7848.08 7846.94 32.00 7846.94 7814.94 1.10 7814.94 7815.84 2.71 7815.84 7811.15 .60 7811.13 7810.53 1285.35 7~810.53 6525.18 1.00 6525.18 6524.18 8.90 6524.18 6515.28 1.15 6525.28 6514.13 10.04 6514.13 6504.09 1.14 6504.09 6502.95 2.71 6502.95 6500.24 .60 6500.24 6499..64 1032.67 6499.64 5466.97 1.14 5466.97 5465.83 15.00 5465.83 5450.83 1.14 5450.85 5449.69 5392.69 5449.69 57.00 5.00 57.00 52.00 8.00 57.00 44.00 -8.00 44.00 36.00 1.00 36.00 35.00 35.00 35.00 -0- (ll2' Above MLLW)RT - - Tubing Han.qer .T,..ubing Data Short Stri 2-7/8" Seallo'ck N Nipple @ 6529' II):1.791 2-3/8" from N Nipple to 6530' _Long String_ 2-7/8" Seallock to N Nipple @ 7862' II):1.791 2-3/8" From N Nipple to 7863' Valve Data · Short String. · XO Sleeve @ 6472' ID:2.313 Long string1 xo s1 eeve @ 6500' 'II):2.-313 xo Sleeve @ 7811 II3:2,313~ 13-3/8" Casing-@ 103,6' 9-5/8" Otis Dual RDH PackL~r @ 6515 .9 5/8"-x 3 1/2" x 3 1/2" 9-5/8" Baker PacJ~er @ 7850' TD 8795' ETD 8747' 9-5/8" .Casing @ 8795' D~.AN~14- . . (:KD. I. EY. / AP~"D. ,, ..... i WELL SCHEMATIC DAT~ T~DING BAY FIELD , ....... J .... j I Original Completion A-26 5-2-72 .....' ~, - -' ....' ........ ~.~~.:::r~~ .... - ................ - ~ OF CALI~RNIA - - - .... ...... . ...... · ~ . _ =_ .,. _ _ - -~ . FORUM 247 (NEW 5/~6l UNION OIL CO. OF CALIFORNIA ,, WELL I~PAIR SHE'ET. D PAGE NO LEASE ' Trading Bay State .... WELL No.A-26-W0 FIELD Trad~.n.q B.a.y DATE 10-26-72 10-27-72 10-28-72 10-29-72 10-30-72 10-31-72 11-1-72 E.T.D. 8795' TD 8747' ETD 8795' TD 8747' ETD 8795' TD 8747' ETD 8795' TD 8747' ETD 8795' TD 8747' ETD 8795 ' TD 8747' ETD 8795' TD 8747'ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Move rig over to Trading Bay State A-26. Commenced operation at 12-O1 A. M., 10/26/72. Opened sleeves in long 2 7/8" tubing string above permanent single packer and above dual hydraulic packer. Circulated filtered Inlet water down long string and out short string. Installed BOPE. Removed Xmas tree. Nippled up BOPE's, failed to test. Replaced API seal ring. Re-tested to 2500 psi, OK. (12 hours working on DC electric power equipment.) Unseated dual hydraulic packer. Pulled and laid down dual 2 7/8" seal lock tubing string and dual packer. Changed and tested rams in BOPE. Picked up 5" D. P. with Tri-State packer picker, bumper sUb, jars and 3 -'6 1/4" drill collars. Found fill at 76.79'. Appeared to be sand and iron oxide as obtained in previous samples. (2 hours working on DC electric power equipment.) Pulled out of hole. Ran in hole with 5' D. P. Circulated out fill from 7696' to 7850' Run in hole with Tri-State packer picker. Milled over Baker model "DA packer at 7850'.. Recovered packer with exception of junk pusher. RIH with 8 1/2" bit and csg scraper. Drilled and washed junk from 8710' to 8740'. Circulated hole clean. POOH.. Made up Reese washing tools.. Ran in hole With Reese washing tools. Washed all perforations with 15% HCL, strapping 3' segments at a time. Circulated hole clean. Pulled out of hole. Ran in hole with Howco RTTS and RBP. Set RBP at 8738' and RTTS at 7850'. Ran tracer survey.. Set RBP at 7852' and RTTS at 7443'. Ran tracer sur.vey. Two-perforated intervals in lower "C" zone with four perforated intervals in upper "C" zone indi.cated tight or plugged. Set RTT.S and RBP over interval 8308' to 8320'. Began injecting filtered water'with 3/4 cfm at 3000 psi, ended injection with 4 cfm at 3000 psi. Set RTTS and RBP over interval 7940'. - 7970' Began injecting with 3 cfm at 2300 psi and ended wit[1 · ll 1/2 cfm at'2700 psi. Set RTTS and RBP over interval 77'20' - 7744 . Began injecting with 2 1/2 cfm at 2700 psi and ended with 5 1/2 cfm at '2900 psi. Set RTTS and RBP over interval 7660' - 7678'. Began inject- ing with 2 cfm at 3000 psi and ended with 8 cfm at 2700 psi. Set RTTS and RBP over interval 7582' - 7500'. Began injecting with 2 cfm at 2900 psi and ended with 4 cfm at 3000 psi. Set RTTS and RBP over interval 7538' - 7550'. Very slow injection and ended at"a. lmost 1 cfm at 3300 psi. Rigged. up GO International. Re- perforated interval with GO International glass Bi-wire guns with 2 HPF, with 2500 psi on interval.. Broke down interval with 1 cfm at 3000 psi. Injection rate increased to 4 cfm at 3300 psi and ended with 9 cfm at 3000 psi.- Reperforated with GO International Bi-wire guns with 2 HPF from 7720' to 7744'. Broke down interval with 8 cfm at 2800 psi. Maintained 5 cfm at 2500 psi. Perfs communicated with those above at conclusion of injection. Straddled interval 7660' - 7678'. Reper- forated with 2 HPF with Bi-wire guns and injected filtered Inlet water at 7 cfm at 2500 psi. Unable to re-set RBP due to residue from guns. Pull out of hole with RTTS and RBP. Reperfprated with 2 HPF from 7582' to 7600'. UNION OIL CO. OF CALIFORNIA ,, WELL REPAIR SHEET D PAGE NO.___.~__ LEASE Tradin.q .Bay. State WELL No.A-26-W0 FIELD Trading B. ay DATE 11-2-72 11-3-72 11-4-72 11-5-72 11-6-72 E. T. D. 8795' TD 8747' ETD 8795' TD 8747' ETD 8795' TD 8747' ETD 8795' TD 8747' ETD 8795' TD 8747' ETD DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS Reperforated with 2 HPF with Bi-wire guns from 7538' - 7550'. Removed junk from RBP and RTTS tool. Replaced cup on RBP. Ran in hole with RTTS and RBP. Straddled interval 7582' - 7600' and injected with 5.5 cfm at 3000 psi and 3 cfm at 2500 psi. Straddled interval 7538' - 7550'. Injected with 3 cfm at 3000 psi and 1 cfm at 2600 psi. Ran RBP to bottom, stopped on fill at 8700' and set RBP at 8698' Set RTTS at 7445'. Ran profile logs while injecting. Rate of 4400 ~WPD at 2400 psi. Retrieved RBP (no fill) and straddled from 7538' to 7550'. In- jected 9 bbls 12-10 HCL-HF mud acid with 120 bbls. water flush. Had slight communication after 3 bbls of injection. Began injection with 3 cfm at 1000 psi and ended with 11 cfm at 1800 psi. Attempted to straddle interval 7720' to 77'44'. Unable to set RBP. Chased RBP to sand fill on bottom at 8690'. Unable to reset RBP or RTTS. PQOH', to replace tools. Straddled and acidized 7720' to 7744' interval with 15 bbls. 12-10 HCL-HF acid with 240 bbls water flush. Began injection with 4 cfm at 6700 psi and ended with 12 cfm at 1800 psi. Straddled and acidized interval 7940' to 7970' with 18 bbls. 12-10 HCL-HF acid with 300 bbls. water flush. Began injection with 8 cfm at 1800 psi and ended with 12 cfm at 1600 psi. Straddled interval 8308' to 8320' and acidized with l0 bbls. 12-10 HCL-HF acid with 120 bbls. water flush. Began injection with 10 cfm at 1500 psi and ended with 10 cfm at 1900 psi. -Pulled out of hole. RIH with 8 1/2" bit and scraper. Found fill at 8664', (sand and emul- sion). Circulated hole clean at 8747' ETD. Acidized 8680' to 8698'. Interval with 8.5 bbls. 12-10 HCL-HF acid with 190 bbls. water flush Began injection with 2 cfm at 2000 psi and ended with 10 cfm at 1950 psi. RIH with bit and .scraper to 8747I. No obstruction, no fi. ll. Ran Baker 4 3/4" x 9 5/8" permanent production packer. Set at 7920'. Set Howco RBP at 1192' in 9 5/8" casing. Changed tubing head. Ran dual 3 1/2" N-80 9.20# buttress tubing strings with permanent Baker A-5 dual 3 1/2" x 9 5/8" packer set at 7342'. Tubing tail, long string 'at 7360, short string at 7360. Tested permanent packer. Set and tested dual packer, displaced annulus with inhibited filtered Inlet water. Landed tubing. Removed BOPE's installed and tested Xmas tree.. Released rig at 12:00 Midnight, 11/6/72. UNION OIL CO. OF CALIFORNIA ~VELL REPAIR SHEET D 4 PAGE NO. LEASE_ Trading Bay State WELL No..A-26-WO FIELD.. Tradin.q Bay DATE E. T. D. DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS TUBING. DETAIL Short String JTS LENGTH BOTTOM 3 1/2" Shear Sub 3 1/2" Ot.is' "N" Nipple 3 1/2" Jt. Dual Hyd. Packer 3. 1/2" Tubing . 3 1/2" Otis XO Sleeve 3 1/2" Tubing 3 1/2" Telescoping Jts. 3 1/2" Pup Jt. 3 1/2" Tubing 3 1/2" Pup Jt. 3. 1/2" Tubing 3 1/2" Pup Jt. 3 1/2" Tubing 3 1/2" Pup Jt. 3 1/2" Pup Jt. Tubing Hanger Landed Below Zero 32 3 58 125 20 .50 1.63 4.10 10.79 62.98 3.65 1001.79 10.69 9.40 · 1657.54 4.20 3914.02 6.21 626.63 3.41 4.47 1.00 36.75 7359.76 TOP 7359.26 7357.63 7353.53 7342.74 7279.76 7276.11 6274.32 6263.63 6254.23 4596.69 4592.49 678.47 672.26 45.63 42.22 37.75 36.75 -0- UNION OIL CO. OF CALIFORNIA WELL RI~PAIR SHEET D PAGE NO 5 LEASE , Tradinq Bay State V~ELL No.A-26-~!O ,FIELD Tra. di~g Bay DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS TUBING DETAIL Long String JT.S LENGTH 3 1/2" Collar Guide 3 1,/2" "N" Nipple 3 1/2" Pup Jt. 3 1/2" X-Over Seal Assembly Locator Sub 3 1/2" X-Over 3 1/2" Tubing ~il 3 1/2" Otis XO 3 1/2" Tubing 17 Dual Hydraulic Packer 3 1/2" Tubing 1 3 1/2" Otis XO 3 1/2" Tubing 33 3 1/2" Telescoping Jts. 3 3 1/2u Pup Jt. 3 1/2" Tubing 56 3 1/2" Pup Jt. 3 1/2" Tubing 142 3 1/2" .Pup Jt. 3 1/2" Pup Jt. Tubing Hanger Landed Below ZerO) .7O 1.68 4.12 ..45 10.65 1.00 .50 31.68 3.65 531.19 12.86 31.13 '3.65 1029.90 10.59 10.10 1750.05 4.12 4453.40 3.43 6.00 75- BOTTOM 7938.60 TOP 7937.90 7936.22 7932.10 7931.65 7921.00 7920.00 7919.50 7887.82 7884.17 7352.98 7340.12 7308.99 7305.34 6275.44 6264.85 6254.75 4504.70 4500.58 47.18 43.75 37.75 36.75 -0- Rotary Table (101' from ~LL~{] .,. Tubing Hanger Telescoping Joints 6263' - 6274' .. 3 1/2" X, 0 (ID:2.750) 7276' 3 1/2" "N" Nipple- 7358'ID:2.635 3 1/2" Shear Sub- 7359 Tail BTM 7360' ID=2.365 3 1'/2" X.o~er. ,7932' " 3 1/2 "N" Nipple 7938' 3 1/2" Col. lar Guide 7936' [ JJ I ,, 0I 36.75' 13 3/8",61# K-55 Butt'. Cmtd. to Surface - 1036 Telescoping Joints 6265' - 6275' L , 7342" Dual Hyd. Packer Baker A-5 3 1/2" X 0 (ID:2.750) 7884' 3 1/2" X-Over 7920' 9 5/8" Single Packer Baker Model D BTM tail- 7939' 9 5/8" 47# N-80 - PllO Butt. 8795' ' DATE FORM 247 (NEW' 5/§§) WELL SCHEMATIC Trading Bay A-26 11/6/72. UNION OIL COMPANY OF CALIFORNIA l PR. AWN., AH"D. SCALE DATE CKD. ~ SHEE"I'$ j SHEET OIL CO. ©ir C,ql~ll' ...... '.Rh, IIA IhEPAIR IFl2CORD SHZIZT A PAGE NO. ]- .!.;,',.'ASE ~ ?ad~]~l Bay State WELL ~O A_-12 P4) W0SPUD DATE 11/7/72 l,~inld_ M'6noi56u P±at-torm CO?.ITRACTOR_',~LC~0 Jt~i:?,!,D.. Trndj__ng Bny , _ LOCATION _C. omlurtnr tt26~ '161.7.'N ~ 571 '~: front ""_2iE_c2~~x~tion 4: TgN, R!3W, S, H. PERMIT NO. 67-88 ____SERIAL NO. ADL - 18731 COMP, DATE 12/8/72 __ RI(; NO. ~56 TYPE UNIT_0ilwell 860I.', DRILL PIPE DESCI{IPTION~" ].q: 50#~ ItTC_ · ELEVATIONS: IVATEI[ DEIq'II 75: ILT. TO OCEAN FLOOR 174' ; T.D. 8475' T.V,D. Lll8' R.T. TO MLLW 101' biS! .... DEVIATION (B.tr.L.) N1077', W4893· ' .. Section R.T. TO PRO~CTION COMPANY ENGINEER Watson Shell ~PROVED: . ................ _ ............... ~ ............. ~ ..... · CASING & TUBING EECO~D SIZE ¥;EIC}IT TH,RE_AD ',. G~ADFT--t DEPTH ...... -' - ---;- 13 3/8" 61# Buttress' J-SS/ f~.6-~' See drilling I)et'_ai!.. REMAaKS 9.5/8" 43.5t~ , Buttraq.q N-80 p-l]0 7490 " " " 7"... ',. 32t,~ ..... x-line P-ll0 8468 ' 'i ' '" .... " ' Lion. er top at 7261' 7'.'....%i.eb~ck..29ji. Buttress N-.80 .,7261 Bb~tom'" .200 .s.x "G" + 1~ CFR2 ~ 1,8% gef'..~. 400 sx ~ "G" + 1% D-51 ~ 2% RS. Topi 600 sx ;'G" + 1% ~FR2 ................. fi 18%' salt fi-200, sx "d'" +...1~ D-31 fi 2% RS. ' -- _J~Z2~_ 9.2_#.-~ Buttress N-80 ....'70~.~57__ See Attached Detail.. . " PERFORATING RECORD D. ATE ' IH2I~EHVAL ' 'E.T.D. , REA.~H --- P~IE_~EliT CO_~LO2{' ., ~/17/72 7700-7~'01' . 8439.'' Squeeze' 100 sx:. "d" cement 2800 psz, 3/17/72 ..7521-7522 " .. ". " 3000 psf'. .... '~ . ~/2J/72_ 6811-68~1 " __ Injection ..2t~F Open ..... ~/72/7.2 6Ra6-6q26. '" " " " . ....... · q12£/72 6960-6980 " ' " " " , , , , , ..... ' ' cement. 3/22/7.2· 7Nq2-7122 " " " Sajleezed V~ 50 sx. 'G' 3/24/72 7160-7180 " " " Open ...... 3120172 '7514-7520 8428' " .... ~ ...... 3/'26/72 7715-7721'."' '" ..... " '" " "' qi26/72 7732-7740 ,, ,, ,, i; · '~ ~ ' ,. $¢27~72 7102-7122 .." "" · ..... ~" Repbrf. Open - 5/27/72 7160-7180 "" "~ " '" Reperf. ~2/2/72 '6811-685i' 8428' Iniectioh ,2, }-~F Op,e,n, R_ep~r£. thru '7" t/'e ba~k. ' 12~2~72. . 6886-6926 " "-. "" " " 12/2/72 6960-6980 " -" "· ~'" '" " "'" " " 12/2/72. , 7092-7122 ;' " " " " ; "' " " '" " ' 12/2/72 7160-7180 "- '"' " [" '~ " ' ~ ' ;~ ~' "'" "' i ' , * .... ~ ' ' ' ' '~---- INITIAL PRODUCTIO:'I W E_L_L_ttE_AD_A_S~£_kt BL Y TYPE:, Shaffer and Cmneron CASING ~EAD: Shd~.fer 13 3/8" k I) 12" series 900 w/ 2'! SE..side. outlets o. CASING HANGER:_._ Shaffer KD 15 3/8'.' x 9 5/8'; hange~ w/ packoff ' o CASING SPOOL: Caneron 12" 900 series x 12" 900 'series AP he~d 'w/ 12" x 7" slips and_seal, ...... · · TUBING HEAD:_ Cani~ron 12" 900 series ~ 10" 1500 series DC-B. ' ! TUBING HANGER: Cameron DC-B 3 1/2" EUE 8 rd top - 3 1/2" Butt. re~s Bottom. TUBING IIEAD TOP: 10" 1500 series br 5000# MASTER VALVES:_,, C,amer,o,n 3 1/2" single block~type - 5000#. CIIIiISTMASTREE TOP CONN.: 3 1/2" I'IIE 8 ~ JUH '2 D!;,:StON C,F ..~L AND GAS ANCHORAG~ · . Document Transmittal Union Oil Company of Cai '~ia union ~o.~ DATE SUBMITTED ACCOUNTING MONTH 6/1/72 To Mr. John Leverson ~ROM Division of Oil & Gas Harry C. Lee AT AT State of Alaska Southern Alaska District TELEPHONE NO. TRANSMITTING THE FOLLOWING: 3 Directional Surveys - Trading Bay Stat~ "' A-25 .... ~u 2 197~. ~l 1,,,~ I ~ '-'~ es, v,:al,...,,-, --- - .~:~~,/. ~- ~.- ?-,.- FORM 369 (REV 2/70) PRINTED IN U.S.A. Document Transmittal Union Oil Company of Cali unlen DATE SUBMITTED ACCOUNTING MONTH 5/30/72 "¥° Mr. John Leverson FRoM Division of Oil & Gas Harry O. Lee AT AT State of Alaska Southern Alaska District TELEPHONE NO, TRANSMITTING THE FOLLOWING: 1 Sepia and 1 Blueline of the following logs on Trading Bay Field A-26 ACoustic GBL- 4/20/72 & 4/23/72 2" & 5" DIL 2" & 5" BHG-Sonic 2" & 5" CNL Porositv-FDC Pc,rositv - 2" Gamma Ray ~- Directional Surveys u,~-~,- F,,9 A- ~-~\ __ / FORM 369 (REV 2/70) PRINTED IN U.S.A, SHORT STRING 'Form P-7 , ~ SUBMIT IN DU.~ATE* STATE OF ALASKA (See otherln- s(ructions on reverse side~ ~. API N~~ CODE OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF W~LL: OIL ~S ~ DRY Other WELL ~ WSLL b. TYPE OF COMPLE~ON: W El,I, ~ OVER EN ~...~ o. o~.~o. Trading Bay State 9. W~L NO. ~on Oil C~~ of C-] i Fn~i ~. 909 ~, 9~ Avenue. ~orage, ~agkm 99501 4. LOCATION OF WELL (Re~ort ~ocation clearly and in accordanoe with any State requirements)* ~t~u,~e Co~uctor ~30, 1606'N ~ 563'~ of SE Co,er, ~c. 4, TDN, R13~. ~ At top prod. lnterfal reported below 5425'~t tot~ ~?~ fr~ s~face 1oration at S 54°~. 6285' out fr~ surface lomtion at S 55°~. 4/1/72 S 4/17/72 I 5/~/72 I 18, TOTAL D~H, ~ & TVD~9. PLUG, MCK MD A ~. ~ ~L'~'~ CO~., ~ 8749'~' ao~ ~v , ~o~ ~oo~ 8795'~, 5674'~ [ 9-5/8"CSg. ~coo,~[ 2 [ ~ta~ L Injection 6450'~ -'4150'~, 7744'~ - 4872'~ - c7 ~d or ~per I "C" Pool. Yes 6. LEASE DESIGNATION AND SERIAL NO. ,, 7. IF INDIA.N, ALLOTTEE OR TRIBE NA_M.E 10. F/~LD AND POOL, OR WILDCAT Trading Bay 11. ~EC., T., R., 1VI., (BOTTO1V~ I-IOm~ OBJIgCTIVE) SE 1/4 of the NE 1/4 of Sec. 8~ T9N~ R13W~ SM 12. PEIR2VIIT 1~O. 24. TYPE EI~ECTRIC AND OTHI~R LOGS RUN ,Schttmuberger DIL, ~ ~ SNP: Dresser G~ Ray. CBL CASI2qG SIZE 13-3/8 9-s/s CASING RECOHD (Report all strings-set in well) ]~¥EIGHT, LB/FT, ~ 'GI:L~DE i DEPTH SET (MD) 47~ [Nan/ [ 8795. t PERFORATIONS OP~ TO ' (In~rval, size and number) HOLE SIZE I CFAfY~NTING RECOl%D I A~MOUNT PULLED 17-1/2 I To surfac- - ~ee c~ment-I Nnn, 12-~a [ ~ ~ csg. detail attch I None ' l for bo~ str~s., ' [ ' ~ 27. TUB~G REOOF~ SC~E~ (~D) [ SIZE DEP~ SET (~D,) PACKER SET (MD) 2-7/8 6530 [ 6515 J 29. ACID, Si!OT, F~C~'~RE, C~tE:NT SQUEeZe, ~C. 7502--7512' 10' 20 holes D~/~II INTI~RVAL (MD) [ AAi£OUN'F 2~ND }2IND OF ~A~P~AL US~ I Unable to sauaeze - nn 7558-7550', 12', 24 holes Aci~z~ 7678-7680' ' ~' 'bre~d~ ~ssible. 7582-7600' 8' 16 holes for { 7660-7678' 18' 56 holes Injection 7720-7744' 24' 48 holes 30. PRODU~ION ~ ~ ~ ~ ~ ~ ,*~m Or *~S~. [IHOURS TESqm. ' ICX-~OXE[ S~ZE [~S're~IP~Om'Zt _SAY 2 197 °' sn' ' _G.~F.__ ] WAX~BBL.L [[GAS'OIL r~ss. 1 I~-HOU¢ aA~ ,I ...... .... ~A~ I I .... [ mws ONP oa I 32. LIST 0~' ATTACHMENTS 33. I hereby 9t~ify th~ th~ foregoing and attached information is complete and correct as determined from all-available records SIGNED ~_ , _ ]~_ TITLE Dist. Dr , 9__m~t_; ViT~ 5/2_2/72 *(See Instructions and Spaces For Additional Data on Reverse Side) Dt~ STATE OF ALASKA <So~structionsOther onln' OIL AND GAS CONSER'~"A:;1ON COM~MITTEE reve,'s~ siae; s. a~~~COn~ , ~~Ni~"-~ WE~L COMPLETION QR RECQMP~ETIQN REPORT AND LOG· ~.~~x~o~ 1.. TYPE OF WELL: 0II,wELL ~ GiS"WELL ~ DR Y'~ Other Injection ,. IF INDI~, ~O~E OR~.] b. TYPE OF CO~PLE~ON: ~-'~ ov~ WELL --.~ , . .... , _.-. :.: ~j-" 6'RAFTi '~. ,,~ o, o~,~o. " A-26 909 W. 9~ Ave~e ~ ~ora~e, ~aska ggs0& ,o. ~m~ ~. ~oon, o~ ~. ~oc~o~ o~. ~.~ -<se~o~t ~oc~t~o~ ct~ ~ ~ ,cco~a,~e~ wita ~ at~te req~e~e~t,~* Tr~~ Bay Xt~u.~e Co~ctor $50, 1606'N ~ 565'W of SB Co.er ~c. 4, ll.$EC.,T.,B,,~.,(BOTT'~ ......... . O~IV~) ~-' ' "' T 9N. R l~f,e~tea be,ow SE 1/4 Of ~e ~ 1/4 of A~ ~o9 p~od. ln~er a 5750' ou~ f~m surface location a~ S 55~W. ~c. 8~ T 9N, R At total dep~ 6285' ou~ fr~ surface location a~ S S5°W' ~. ~~o. .4/;./72 4/17/72 , I 5/2/72 RT 18 'rOTAn DEPTH 1VID & TVD~XO~PL.~(~.]~%~CK M_D___& ~. ~ ~L'x'~LE CO~L., 21. INTERVALS DRILLED BY ' ' I ~--~/~" ~O ~1~ I ~OW~Y* aOTARY TOOLS ' CABLE TOOLS ' 5674'~ J ' ~' J 2 ' ~ ~. ~VA$ D!~cTIO~ 22. PRODUCING INTERVAL(S), 61~ ~'~II~-~O~vlI~T~N--'~OP, BOTTOM, NAME (MD AND TVD)* Lower "C" Pool - 47-5, 50-5, 51-6 Sands. Top 7940'MD. 5028'VD; Bottom 8698'MD. 5610'VD 24. TYPE ELECTRIC AND OTHER LOGS RI3N ' Schl__mS~_ rger DIL, ?DC. SNP: ]~esser Ga~,a Ray. I~BL. 25. CASING RECORD (Report all strings~se% in well) CASLNO SIZE WEIGHT, DEPTH SET 0VID) HOLE SIZE 13-3/1~ 61# 9-578 47# CF-,%fANTING RECORD SURVEY 1V~ADE Yes I A~V[OUNT PULLED 26. LINER 1~ F. COE/) SlZl~ 't TOP (MD) J · BOTTOM (AID) J SACKS CEMENT* " i 28. PERORATIONS OP~ TO PRODU ON' (In~rval, size and number) 7940'-7970' - $0' - 60 holes 8308'-8520' - 12' - 24 holes 8680'-8698' - 18' '36 holes i Acidized for Injection PRODUCTION SCP~EEN (MD) SIZE TUBING HE C~OP~D DEPTH SET (iV~D) [ PACKER SET (MD) ! ! 2'3. ACID, Si!OT, FJi. A~C~'CrRE, CEE, IENT SQUEEZe., ETC. D------------------~/~I INT]iZiVAL (MD) J ASiOUNT /~D KIND OF M~%~P~ US~ 8698-8700 1. ~zd w/2~0 sx "G" ~t - ok 8320-8522 J~zd w/ZOO sx "G" ~t - ok 7970-7972 ~zd w/200 sx "G" ~t - ok DATE FIRST PI%ODUCTION [ PllODUCT1ON ME'IHOD (Flowii~g, gas lift, pumping--size and type of pump) JWELLunut.in)STATUS (ProducLng or i CI%OIiE SIZE jPROD'N FOR OIL--BEL. G,~S--IVICF. WA~qgl%--BBL. GAS-OIL R~%TIO TEST PA,T~!OD ----~- I~SS. J ' J~-HOUR R~ _ LI 32. LIST 0F ATTACHMENTS DIVISION OF OIL ~O GAS 33. I hereb~ e~7 tha~he ~regolng ~nd attached lnformatlon 1~ eo~et a~ determined from alFavaHable reeorOs SIGNED ~ '~ ~~TITLE "''t= ~ S"*~. DATE 5/22/72 *(See Instructions and S~ces [or Additional Data on Reverse Side) .. I;EASE- _ 1;'IEI,D LOCATION .~R · · WELL N O._ _.k-2.6_- P,~.CO,~D ~_~ PAGE NO. ~ . SPUD DATE ... h-1,72 COMP. DATE ~-1-72: CONTRACTOR W0DE~O RIG NO.~ TYPE UNIT . _ 0j~weli 8~ ~ectric ,,. ' DRILL-PIPE DESCRIPTION_._..~" ..... .19,~ · PERMIT NO. SERIAL NO. T3).~_8795' T.V.D. ~527 DEVIATION (B.3I.L.) 3l~ ' , COMPANY ENGINEER ~ork - Watson - She~ ELFA:ATIONS: WAq'EI~ DEt~'it 62' '- ,- ~LT. TO OCEAN FLOOR '!7~'... R.T. TO MLLW !0l' ti. T. TO 'D~[I,L DECK .... 22;0+'. "' R, T. TO PRODUCTION DECK h0.82 ~ ~PROVED: CASING ~e TUD!NG RECORD ~--Slzs V:E[diiT ..T. Hnr~,\D ca,xm: ,j DHv'rH . : RZr4~)n.~S .. , , I'a ~/8' ~I~ ~i~t+.-.*~' ~ gg 10~6' Cemented ~ surface - g~ Bx Perlite& 2Q0 Sx'G' ' so2- ilo hOG sx. o i.8oo . Second Staae - 8m Sx 'G' w2'~ Gel &'[ iff, 'Perli'~e/ ~ & t% D 31~%0 SX ,t' W/, !$, D 31." .. , ,. ~_ .. nAT~_ t INTERVAL ..... Z.T.D_ . ~~~..,j . ....... -... ........................ -PR' ESEI~T' CO,.~DI~" -I lQ,{ hrgn-7~ 8698-Rvnn, 87;~.9' Sqn.~za ~1 ,' ~Squ!.?zed ~.th 200 .Sacks ~t to. 27~ PSI .h~1.7~ 8~2o~22, fl?},q, ~ueeze ~2 Saueez~- ~%h'~O. . .. . ~a'cks' ~t- to 2450 PSI ~. . - -- _ o~ ks Cmt.,,Tes~' to 3~ PSI 4~1.72 7970.7~72' . _ 8~' ,S_~eez$, ~3 1SQuieez,~d. ~h' 200" c _ , . , . ~ ~ · .. , . ..... ~'~~ 7~02-7512' / 8789' %~at~r LnJe 2 HPF ACidiz~ .. . .... 75.38_7~50, ' , . ~a~12 8789 · ~aSer. ~j'. 2~F' ACidiz~' ~5 72- ~5~2-7600' ~789' Water ~J..' ~-2 ~F Adtdiz.ed~ " . -. '~25-72 '~6~-7678' 8789' ' wa~r'Inj~. 2 ~F ACi~z~'' - -~2~7~ 7720-77~, 8789" ' Wa%~ ~j~ ' 2"'~F "Aci~Z~ ' '" ' ' · . , , , ,, , . .... ~ ~ ~ ~ .-... .,. . ~ , , ~ . . . , ,, , .. J , · INITIAL PRODUCTION _.DATE IHTERVAL' i N_~T O~L CUT 'GR~;V.[ C.P. ' T.p. ' CI*O%.'E ~TC.F GOR '] RE'_~A.~fS · - , , · ,, · . · · WELL Pi~D_A_S S E ~. Y TYPE: C~s ~ren - CASING ~EAD: 1~ 3_/8" S .0W.x 12"' ~000~ .WI~'.' w/ 2" ~~-nKd ~t~ ~ ~' " . - -. . - . ' . CASING 'HANGER:,, TyFe .n~_" .~p~ & s~al ass~b~v- }~" x 9 ~/8" ~'~ "R' Seal' . . CASING SPOOL: ~' . o 'TUBING HEAD: !~" )000~ x 10" ~)9~/~ ~.~ ,/%~o 2" ~0,00~ s'tu~i~d ·outlets ~BING HANGER:_ bC-B 2-7/~" x 2i7/8" E~ 0rd %09 a~ bot~J "' ' -. TUBING HEAD TOP' 10" 30~ ~'ina~ "' ' MASTER VALVES: ~0~ single str~ block-leg t~ w~th beton flange 10" CHRISTMAS 'FREE TOP CONN.:, g..~. 8 t~/1~11~ ~q~ Vii.. ~-,~J. ~.~r. ~.,?LI..IF~.~r-~INI~ ~,n~i ~ MUD RECORD Page NO. 2. LEASE $%:%-_ WELL NO._A-26 FIELD T~Ing Bay_ TYPE S,a w:%.? (ff;~ DISTRIBUTOR ~a_k:,cobar DATE t DE.PTH WEI~GHT, VISC_._ W. PH SALT OIL SAND SOLIDS .... REMARKS 2,. 1048 76 c;la ll, 'lO.rl 20 u . 1 !5- , 7 h~lO 78 ~3 9 !c,.~, ~8 ~ h · 13 8 gl~ '79 gh . lo lo.~ - lO q8gl 8o h5 ~o ad,5 ~s u h a 15 , 11 6~81 77 .... ~ lO lo '1~ 7978 79 ~0 8 10 1~ 879~ 79 55 8,5 ~o 25 u la ~ ~l, 19 " 79 gq 8.g ~0 2o -. 8o 5h ~ ~ .22 ~ 8o h8 tg ~1 ~7~ ~ 3 ~ ~, " 23 " 78 gq 20 11 20 U '2 1. ~ 1~ ~an~.d +.o' ~al+. wat~. 24 ~ ?0 Filt. ered ~ Let w . . ~ ' -,.. ~ .,,~.. 26. " ' 6~ , 27 '" " ~ ) " ' ' .' , . ,- ,, :'29 " " " " -" LEASE UNIC ' OIL' CO..OF CALIFO IA DRILLING RECORD SHEET D 3 PAGE NO. Trading Bay State WELL NO. A-,26,, ,FIELD Trading Bay ,,, DATE E.T. D. DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS 4/1/72 -3 10 11 12 13 14 15 16 17 620' 1048' 1048' 1888' 2955' 3758' 4510' 5132' 5541' 5851' 6581' 7024' 7578' 8065 ' 8486 ' 8725' 8795' Began moving over conductor #50 at 1201 am. Tagged bottom of conductor at 178'. Drld 12-1/4" hole 'to 500'. DDrld ~ surveyed to 620'. DDrld B surveyed to 680'. Drld B surveyed to 1048'. Opened hole to 17-1/2" to 963'. Cont opening hole to 17-1/2" to 1048'. Circ 5 condition for csg. Ran 26 its {1038') of 15-3/8" 61# K-SS buttress csg w/shoe at 1036', ~ float collar at 996'. Cmtdw/S00 sx Class "G" cmt premixedwith 1/2 cu.ft. perlite per sack, 4% bentonite, 1% CFR-2 followed by 200 sx "G"w/l% CFR-2 ~ 5% CaC12. Good circ w/4S0 cna.ft, cmt~ returns to surface. Bumped plug w/1000 psi, float held. CIP 9:20 a.m. 4/3/72. Broke out riser system, cut csg and welded head. NU BOE. . Fiixished nippling up BOE. Mixed fi poured 15 sx Class "G" cmt around 13-5/8" csg, where cmt had fallen- away. Tested blind rams, choke ~ kill lines, etc. to 2500 psi. RIH. Tested pipe rams ~ hydril w/1000 psi. ok. Drld plug, Cmt ~ Shoe to' I048'. Drld '~ surveyed 12-1/4" hole from 1048' to 1888'. POll. Layed down 26 its of dp. PU locked in drlg assem. RIH w/bit #4. -Reamed tight hole at 1200'. Raamed ~ washed 1600' to btm. D ~ S 12-1/4" hole from 1888' to 2955-'. POH to change bit. POll. Hole very tight. Deld ~ surveyed I2-1/4". hole 2955'-3758'. Drld ~ surveyed 12-1/4" hole 3758'-3977'. Drld & surveyed 12-1/4" hole 3977' to 4510'. Drld 6 surveyed 12-1/4" hole 4510' to 5132'. Drid $ surveyed 12-1/4" hole 5132' to 5441'. POH to pick up DDrl to rum direction to the left. RIH w/DDrl 6 bit #9i. DDrld~ surveyed 12-1/4" hole 5441'-5541'. DDrld '~ surveyed 12-1/4" hole 5541'-5591'. 'Rill w/bit #10. Drld ~ surveyed 12-1/4" hole from 5591' to S851'. Drld 12-1/4" hole 5861' to 6581'. Check BOE. Drill 6581'-7024'. Check BOE. RI ~ drill 7024'-7578'. . Drld 7578t~8065'· Drld 8065'-8486'. DIVISION OF OIL AND t,~A~ Check BOE. Drill 8486'-8725'. Circ 1/2 hr pull 10 stds. Ran back to btm. Circ ~ condition mud for logs. PO. RU ~ run Schlumberger DIL log. Ran FDC-SNP log. Ran Schlumberger logs 16-1/2 hrs. RD Schlumberger. RI to 4570. Circ 1/2 hr. Ran to 8675, circ ~ ream to 8725. Drill 8725'-8795' ~ circ 1 hr. ./ DRILLING RECORD T D I IAY D 1§72 4 LEAS~. Trading Bay State DIVISION OF 0~1. AND C WELL No..A'26' ' FIELI~~Ig. Bay . DATE 4/18/72 2O 21 E. T. D. 879S' 8749' 8749~ 8749~ DETAILS Of OPERATIONS, DESCRIPTIONS & RESULTS Circ at 8795'. Made short trip. Reamed out 8110' to 7940'. Rill. Reamed washed 8715' - 8795'. Circ ~ 'condition mud at 8795'. Surveyed. POH to run csg. RU [ ran 53 its 9~5/8'' 47# Pll0 [ 169 its 9-5/8" 47# N-80 buttress csg. Howco float shoe at 8795', float collar at 8751', self fill collar at 8749', ~ DV cmtng stage collar at 2107'. Circ before crating because of emergency situation .on Grayling. Bottom Top 8795.00 8792.90 2.10 8792.90 8752.46 40.44 8752.46 8750.66 1.80 8750.66 8748.58 2.08 9-5/8" Cas.lng Detail Length Jts 8748.58 6713.98 2034.60 6713.98 2109.65 4604.33 2109.65 2107.50 2.15' 2107.50 59.00 2068.50 39.00 -0- 39.00 52 117 52 'D6'sEription 9-5/'8~;'' t6wCb ~'toat Shoe 9-5/8" 47# Pll0 buttress casing 9-5/8"' ttowco Float Collar 9-5/8" t. Iowco Self Fill Diff. Fillup Collar 9-5/8" 47# Pll0 buttress casing 9-5/8" 47# N, 80 buttress casing 9-5/8" Howco DV Stage' Collar 9-S/8" 47# N-80 buttress casing Elevation To'tal .... 9.70' Cut OFF Circulated. Cmtdbtm stage w/400 sx Class "G" cmt mixed w/548 cu.ft, gel water, plus 800 sx "G" w/gel r4~ t o~ ~ .1/2 cmft. perlite per sack'added ~ S00 sx "G" w/l% D-51. First Stage precededbymud'sweep. Dispw/3599 cu.ft, mud. Bumped plug. CIP 3:50 a.m. 4/19/7'2. ~ened DV, circulated. Took on cmt from boat. Cmtd second stage w/800sx "G" cmtw/ 1/2 cu.ft. /erlite/sack, 4% gel ~ 1% D-S1 added, followed by 1SO sx Class "G" cmt 1% D-31. Perlite mixed to 96#/cu.ft. slurry ~ naat mixed to ll6#/cu.ft. slurry. Displaced. Bumped plug. CIP at 8:25 a.m. 4/19/72. -Approximately 370 cu.ft, cmt to surface. Removed riser. Landed 9-S/8" in Cameron "CA" slips. Instld Cameron 12" 3000# .x 10" 5000# tbg head. Tested tbg head to 5000# ok. Installed riser, BOE, flow llne, etc. Tested BOE, choke, kill lines, riser to 2200 psi. ok. Worked on electrical panel for 2 hrs. ~'~de up clean out drlg assembly. RIIt[ DO.[ tstd DV. Ran to btm. CO to collar at 8749'. Circ clean. RU Dresser-Atlas. Ran CBL ~ GR .logs. RD Dresser-Atlas. Rill w/Howco RTTS. Hung RITS at 8557'. RU Dresser-Atlas and RI to perforate 4 hpf at 8698'-8700' with thru tbg guns. Perfd 4 hpf 8698'-8700' w/Dresser-Atlas. Set RTTS at 8557'. Brokedown perfs, w/5500 psi. No rate. Spotted caustic water across perfs. Brokedown wi'th 2800 psi. Established rate of 15 CMl at 2700 PSI. Pm~ed 50 cu.ft.' wtr ahead;-200 sx (228 cu.ft.) Class "G" mt w/l% D-51 added 6 20 cu.ft. wtr behind. Dispw/SS5 cu.ft, mud. Closed tool. Sqzdw/add'l 319 cu.ft. mud to a standing press of 2700 PSI. Bled off press [ cmt flowed back. Repressd to 2700 PSI 5 times. Press held 5rd time.- Did not flow back. CIP S:00 a.m. 4/22/72. Total time 1 hr 20 min. Released RTrS. Reversed clean. Pulled to 8131. First sqz left theoretically 25 cu.ft, slurry in csg. RU Dresser Atlas 5 perfd 4 hpf 8520'-8522' for sqz #2. Brokedown with 2700 psi. Rat 2 cfm at 2800 psi. Rate 2 cfm at 2800 psi. Pumped 100 cu.ft, wtr ahead, 200 sx Class "G"w/l% D-31 and 20 cu.ft, wtr behind. Dispw/465 cu.ft, mud. Closed tool...Sqzdw/564 cu.ft, add'l mud to.a standing press of 2450 psi. Total time 1 hr ~ 45 min. CIP 11:50 a.m. 4/22/72. Reversed clean. Pulled to 7820' Left 45 cu.ft.slurry in csg. RU Dresser ~tlas [ perfd 4 hpf 7970'-7972' ~or sqz.#5. Brokedown at 2000 psi. Ran 6 cfm at 1800 psi. Pumped 100 cu.ft.' wtr, 200 sx "G", 20 cu.ft, wtr, 452 cu.ft. mud, Closed tool. Sqzdw/total 822 cu.ft, mud but obtained no buildup in pressure. Over displaced 40 cu.ft. Reversed clean. Attempted second sqz. Could not get breakdown to 5200 psi. Pulled to 7508'. RU Dresser-Atlas. Perfd 4 hpf from 7678'-7680' for sqz #4. Pm~d 100 cu.ft, wtr w/caustic (2sx) md spotted across perfs, after unable to breakdown w/5400 psi.- Pulled up to breakdown perfs. LEASE DATE 4/22/72 23 24 25 26 UNi OIL C · DRILLING Trading Bay State E. T. D. 8749' 8789' 8789' 8789' 8789' SHEET. D · PAGE NO.:. 5 WELL NO .... ~_~.~. _': Bay.. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Brokedown perfs w/3200 pSi. Rate 2 cfm at 2800 psi. Pumped 100 cu.ft. wtr, 542 cu.ft. (300 sx) Class "G" cmt slurry, 20 cu.ft, wtr ~ 287 cu,ft, mud, Closed tool. Press increased sharply to 5700 Psi., varied from 3400-3700 psi £or a few minutes, then remained constant at 5800 psi with a rate of 2 cfm. One hr ~ S0 min from beginning of job .~e pressure increased, to 4500 Psi. The sqz was stopped ~ attempt was made to reverse circulation. Could not circulate either way, after release RTTS. Pulled' 'string wet, Layed cmt its dwn. PU drlg assem ~ Rill. Found cmt stringers at 7441'. Drld out cmt to 8700'. Broke coupling on rotary shaft. Rprd or welded coupling. CO to 8789'. Circ hole clean. POll. RU Dresser-Atlas. Ran CBL-GR log from 8789'-7250'. POll. RD Dresser-Atlas. Rill w/Howco RTrS to 8789'. Dispmud w/filtered Inlet wtr. Weighted Inlet wtr to 70#/cu.ft, Pulled RTTS to 7450' RU Dresser-Atlas. Per£d 2 hpf 7502'-7512,. With RTrS set at 7450', groke these perfs w/1800 psi. Injected 'S CF~.! at 2250 PSI. Ran RTTS to 7544' ~ tstd to determine if perfs below were-holding. Tested to 2250 PSI ok. Pulled ~-set RTTS at 7449'. Opened tool. Rigged Dowell. Pumped 400 gals 2-1/2% HCL, 750 gals mud acid ~ 400 gals 2-1/2% HCL and 72 bbls of wtr. Closed tool . tkunped 2 cfm at 2200 psi until' HCL reached perfs ~ press decreased. Holding 2200 psi, the rate increased to 4 cfm. Later it increased to 14 cfm when mud acid hit perfs ~ 16 cfm before last HCL was past perfs. Washed with 150 bbls filtered inlet wtr w/final rate of 12 cfm (3100 BPD). Rigged Dresser ~ perfd 2 hpf 7558'-7550'. Completed perforation, rigged down Dresser=Atlas. Set RTrs at 7525. Rigged up Dowell. Opened RTTS, & pumped 480 gals 2-1/2% tlCL, 900 gals mud acid, 480 gals 2-1/2% tlCL ~ 400 cu.ft, wtr. Closed tool & began injecting at 1 cu.ft./min. Breakdown was taken at 2100 psi ~ fate established at 2 cfm at 2200 ~si. With 800 psi on annulus while pumping, communication was observed. Annulus pressure increased to 2000 psi while trying to inject acid into interval 7558'-7550'. Pumped 180.bbls filtered Inlet wtr at 2000 psi at 5 cfm. Rigged Dresser Atlas ~ perfd 7582'-7600'. Tested RTTS to 2100 psi W/pkr at 7667'. Moved pkr to .7574', unable to .breakdown at 2100 psi. Spot 10 bbls mud acid across perfs. Set pkr at 7574'. Brokedown w/2000 psi. Rate 5 cfm. Blaintain 1500 psi on annulus thru breakdown. Press increased to 1900 psi (communication). Disp the 10 bbls acid at 4-1/2 cfm w/1800 psi.:= )<hd acid to perfs press gradually dropped. ~.~d acid out to I050 psi.. Rate increased to' 1S cfm. Inject 270 bbls filtered Inlet wtr at 1050 psi, 15 cfm. Rigged Dresser Atlas ~ perfd 7660'-7678'. Set RTTS at 7698'. Test to 2100 psi. Spot 10 b~ls mud acid across perfs 7660-7678. Set RTTS at 7656'. Brokedown at 1900 psi 2 cfm. Pumped 720 gals 2-1/2% tlCL, 950 gals mud acid and 720 gals 2-1/2% ttCL. Displaced to tool & closed tool. Disp at 1900 psi at 11 cu.ft.per min. Broke psi when mud acid hit perfs, 650 psi 13 cfm. Injected 270 bbls filtered inlet wtr at 650 psi at 2-1/2 bbls per min. Rigged Dresser Atlas ~ perfd 7720'-7744'. Spot ' 10 bbls mud acid across perfs. Set.RTTS at 7698'. Close tool. Broke- .down at 1S00 psi, 12 cfm. Disp acid'open tool. Punp 900 gals 2'1/2% HCL, 1580 gals mud acid, 900 gals 2-!/2% IICL. Disp. to tool ~ closed tool when acid to tool. Broke back to 700 psi at 2-1/2 bpm. Disp acid w/180 bbls Inlet wtr at 5 bpm. Rigged Dresser Atlas. Perfd 2 hpf 7940-7970'. Spot 10 bbls mud acid across perfs. Set RTrs at 7916'. Brokedown at 1900 psi, 11 ~fm. Disp acit ~ open tool. Pump 1200 gals 2-1/2% tlCL, 2000 gals mud acid ~ 1200 gals 2-1/2-%. tlCL. Disp to tool ~ close tool. Pumped acid to perfs. Broke back to 1400 psi at 12 cfm. Disp acid w/450 bbls filtered Inlet wtr at 1400 psi at 5 bpm. Rigged Dresser Atlas. Perfd 2 hpf 8308'-8520'. Spot 10 bbls mud acid across perfs. Set RTTS. at 8289'. Brokedown 1850 psi, 5 cfm. Pump 480 gals 2-1/2% IICL, 800 gals mud acid, 480 gals 2-1~2% IICL. Disp to t6ol. Z '-40 ~ r , CA$1hG V,/E:t GHT STATE .~;~OMPLETIO N OGAS LIFT EQUIPMENT OPACKERS AND ACCESSOR.IES )UIPMENT 0 POST COMPLETION EQUIPMENT DESCRIPTION OF EQUIPMENT AND SERVICES ! ~s..'~.. ~ ?.<,.:- ~.~.. / ' A , · IESTIMAT£ / -J,../::, ... ,,,- TOTAL ESTIMATE COMPLETION PROC:E.O tJ RE · PR F. PAR. ED I~Y OFFICE .// , . I ' " I , CASING LINER S~ZE I '"'" GAS LIFT EQUIPMENT OPACKERS AND ACCESSORIES I O SAFETY EQUIPMENT OCOMPLETION EQUIPMENT POST COMPLETION EQUIPMENT : · DESCRIPTION OF EQUIPMENT AND SERVICES I · .-.~ .,,*,.., ,,' ? , .,. J ·-'". '--'_C.' ' ' '~' '-:":'" ' > .... /-: ,/.L ' .:._' ' "' ' '":':' ' ~'~ ' ~' -" ~ ~"-' ,. ,. '~' / "'~ , : · 'i' .; ' . . .,":, ,"; ..d"~, '- ': ' :-' .' · ,~ / .;' .,, ;--> U C /.?.~ .m ,..' t ;:STIMATE .'" TOTAL ESTIMATE J I COMPLETION PROCEDURE; '~-" -' D I R E C T I O N A L S U R V E TANGENTIAL. ,METHOD ................... UNION.._OIL..OF..CA ~ELL. A-26 ._ WELL.. COMPLETICN R PT ..... 04Z20/72_ PREPARED._B_¥_SCS ................................... MEASURED D E V I A T I 0 N TOTAL COORDINATES C L 0 S U R E S DOG LEG SECTION DEPTH ............ ANGLE ......DI R,ECT_I ON ............ TVD ................. SUB ....SEA ............ LAT. I TUDE__DE~ARTURE ......... DI STANCE .......... ANGLE_ SEVER I.T.Y__QISIANCE_. ORIGIN LOCATED AT MD = 0o00, TVD = ...... 273 ............ 0 ..... O' ........ N ..... OE 273,00 .................. 172, 295 0 45' N 45E 326 I O' S 25W .... 388 . . __.4....2 5.! ....... S.... 2.6 W.._ 419 6 20' S 33W 481 9 30' S 42W . _512 ..... 1.1___15Z ...... S,_47W_. 5'74 14 30' S 43W 605 15 30' S '32W 294.99 193- 325.99 224. 387.80 ......... 286. 418.62 317, 479.76 378. ..... 510.I~ .............. 409. 570.19 469. 600.0'1 499. .... 636 ........ 17...30! .......... ~_,35W ......... 629.63 .... 528. 680 17 30' S 40W 671.60 570.60 803 21 15' S 48W- 786.23 685,23 ..... 925 ...... 24 ........ 0.~ ...... S_._47W ....... 897,.69 ............ 796,69 1048 26 45' S 47W 1007.52 906.52 0,00, LATITUDE = O0 .................... 0.'00 ............ O. 99 0'20N O. 99 0.28S O. 80 ............4.57S ......... 2. 62 7.44S 3, 76 15.05S 10. 17 19,17S ......... 15. 19 30.52.S 25. 07 37.55S 30. 63 45.19S ........... 35. 55.32S 44. 85.15S 77. 118.99S .... 113. 156.75S 153. 0,00, DEPARTURE = O0 ................. 0.00, ........ 0 20E 0.28 N 45 02W 0.28 S 4 I1W ._5..04,_S .... 24 98W 8-44 S 28 82W 18.54. S 35 25W_ ___24.50.._S_.38 83W 39.99 S 40. 22W 48.20 S 38. 57W ........ 57.5.1_S_38. 07W 70,73 S 38. 20W 114,94 S 42. 49W ..... 164,44-.S-.43, 98W 219.73 S 44. 1263 36 15' S 48W 1180.91 1079,91 _,1482 ............ t0,.,15! ....... S_,_51W .......... 1348.06 ......... 1247.06 1702 47 O' S 52W 1397.09 1888 56 O' S 52W --2086--~.~_55._.45! ......... S._.5.1W ........ 2459 56 O' S 49W 2832 54 45' S 51W .... 2955 .... ...-_54_. O~ ........ S .... 51W ..... 3324 52 15' S 53W 3696 5I I5' S 57W 1498.09 1602.10 1501.10 524.86S 606. 17.13.54 ............ 1612,54 ........... 627,86S ........ 733, 1922.12 1821.12 830.73S 967. 2137.39 203'6.39 1022.4'3S 1204. 2209.69 ........ 2108,69 ....... ] ....... 1085.05S .... 1281, 2435.60 2334.60 1260.64S 1514. 2668.44 2567.44 1418.65S 1757. 241.82S 248.46W 346.71 S 45. 330,87S ....... 358.43W ...... 487..80....S._47. '22W 648.29 S 48 4'29,93S 485. . 73W 802.25 S 49. 92W ......... '965.84 S.._49. 30W 1275.07 S 4.9. 03W I579.57 S 49. 36W ..... 1679.05....S_49. 37W 1970.42 S 50. 68W 2258.77 S 3977 ......... .~0 ....... 0 ........ S._58W ..... 2849.07 .......... 2748' 0.7 ......... 1532.72S .......... 1940.23W ...... 2472.60._...S 51 4280 54 O' S 60W 3027.17 2926.17 1655.28S 2152.52W 2'715.39 S 52 4543 58 O' S 59W 3166.53 306.5.53 177,0.16S 2343.70W 2937.08 S 52 ..4.784. __,___5 8_..,3 0. ~._~.S=.~ 61 ~;'L_.__.3292,46 ....... 3191.46 ........ 1869.78 S ..... 2523,. 43W _ _~..3140 '66_ S.._53 5060 58 O' S 61W 3438.71 333'7.71 1983.25S 2728.14W 3372.84 S 53 5437 57 15' _5 6.31 ......_5.6_ ..... S 65W 3642.66 3541.66 S._.53.W 3751_.15 ........ 36.50 .. 15 ..... 2t17.25S 3015.51W 3684.57 S 54.92W ._221.4,0 5S_L_3.1.~.3,,.9 5W_ 38.4.5..32__S_54_. 8.4. W_. ..... 0.00 .00 ........ 0,000 .......... 0.0.0_ .OOE 3.4-09 -0.28 .98W 5.561 0.18 .82~ .... 5.511 ..... 4..3.~_ .12W 6.523 7.52 .73W 5.469 17.49 ,49W .... 6.343..~23.48__ 24W 5.432 38.65 83W 9.716 46.28 21~_ 3.010~55..03__ 54W 3.416 67.81 19W 3.728 112.04 64W 2.275 ...... 161.17- 49W 2.235 215.98 77W 4.425 342.14 28W__.2.013 .... 45W 3.0~4 643.95 13W 4.838 797.93 45W,..~ .......... 0.436 .......961.18_ 34W 0.448 1268.66 66W 0.554 1572.50 74W ...... 0.,609 .... 1671.75. 22W 0.642 1963.32 ogw 0.886 2253.28 .69W____0.523 2468.26.. .43W 1.418 2712.49 · 93W 1.553 2935.01 .46W ......... 0.735 ..... 3139,~0_ .98W 0.,181 3372.22 0.917 3684.55 5.202, 3845.28__ '- ~ D I R E C T I O N A L S U R V E Y TANG EN ltIAL. _METHOD ............ UN I. ON_OIL... OF_. C A....N E L L...A. 26_ W EL L._C OM P. L ETi ON_R PI__O.4.Z20 Z_72.._P_R EP. A R E D_.B_Y__SCS MEASURED D E V I A T I 0 N DEPTH .......ANGLE ....... DI.,REC ,T ION TOTAL COORDINATES C L 0 S U R E S D TVD ............. SUB..SEA ....... LATITUDE ...... DEPARTURE .... DISTANCE .......... ANGLE ..... SEV 5725 59 30' S 52W .... 5975 ............ 61 6320 61 0j S 52H 6581 59 45~ S 52W __6905 ............ 58...45.~ ......... S .... 55W_ 7024 58 O' S 55W 7378 57 15' S 57W 7. 75 0._ 8179 44 30' S 58W 8486 39 0' S 59W _.8.725 .......... _3~._.30.[__._S ....61W. _ 8795 34 30' S 61W 3798.85 3697.85 2263.91S 3207.78W 3926.21 S 54.78W 3919.10 ........ 3818.10 ..........2398o85S.~.]_3380.49W ......... A145.15._S...54..63W ...... 4086.36 3985.36 2584.62S 3618.27W 4456.59 S 54o46W 4217.85 4116.85 2723.43S 3795.94W 4671.86 S 54.34W 4385..93 ........ ~284.93 ....... 2882.31S ...... 4022..83W.___4948.83 ..... S.....5~..37N 4448.99 4347.99 2940.19S 4105o50W 5049.74 S 54.39W 4640.49 4539.49 3102.34S. 4355.20W 5347.18 S 54.53W 4875.86 ..... 4774.86 ........ 3263.~3S ..... 4594.02W .... 5635..16_S_.._5~.61W 5181.84 5080.84 3422.78S 4849.02W 5935.35 S 54.78W 5420.43 5319.43 3522o28S 5014.63W 6128.05 S 54.9IW ,_.5615.00 ........5514.00 ....... ~589.57S ..... 5. I36.01W .......6266.07_S_55..05W~~ 5672.69 5571.69 3608.79S 5170.69W 6305..51 S'55.08W PAGE 2 OG LEG SECTION ER I.T Y__QIS I~ANC E_ 3.830 3926.16 0.700 .... 4145.02_ 0.072 4446.33 0.478 4671,.46 0..853.. 4948.45__ 0.6.30 5049,37 0.522 5346.93 1,760 5634..97_. 1.496 5935.27 1.804 6128.02 ..1.5 z~9______6266 ,, 1.428 6305.51 CLOSURE 6305.5I S 55- 5' W JUN .2 '1972 _ DIVISION Of OIL AND ~.;',.; · . DIRECTIONAL SURVEY PAGE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB SEA DEPTH UNION OIL OF CA WELL A-26 WELL COMPLETION RPT 04/20/T2 PREPARED BY SCS TANGENTIAL METHOD _.MEASURED ....... TOTAL., .COORD I NATES ....... MD~.T.VD ....... _VERTICAL_ DEPTH TVD SUB SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION 301 .... 301.00 ....... 200.00 ................ O.ION ............. 0.15[: 401 401. O0 300.00 '5. 805 -2.91W 503 501.00 400.00 -I7.93S -13.91W ..... 606 ..... 601.JOQ .... 500.00 ........ ~37.79S ..... ,30.39W_ 712 701.00 600.00 -62.97S -52.57W 819 801.00 '?00.00 -89o6~S -82. O'IW ........ 929__ 901.00 .......... 800.00 -120.13S ...... ~.114.72W_ 1041 1001.00 900.00 -154.51S -151.58W 116~ 1101.00 1000.00 -202.61S -204.92W ..... 1289,.__ 1201.00 ..... 1100.00 ......... ~252.52S ...... ~261.68W 1420 1301.00 1200.00 -305.79S -327.47W 1560 1401.00 1300.00 -365.82S -403.16W .... 1707 1501,00 ...... 1400,00 ..........-432,57S .........-.488,6iW 1886 1601.00 1500.00 -523.85S -605.43W 2064 1701.00 1600.00 -616.26S -719.60W 0 0 2 11 18 28 40 63 ......... '88_ 119 159 206 285 363 _,_2242 2421 2596 --2769 2940 3104 .... 3267 3428 3588 ._3747 3902 4065 .__4235 4419 4609 1801,.00 ...... 1700,00 ............. -712,92S ....... ~831, 1901.00 1800.00 -810.19S -943. 2001.00 Lgo0.o0 -900.97S -1054. 2101.00 ......... 2000,00 ..........-990,02S ...... ~1164, 2201.00 2100.00 -1077.52S -1272. 2301.00 2200.00 -1156.02S -1375.53W 2401,00~= ..... 2300.00 ........ ,12.33,74S ...... ~1478,68W. 2501.00 2400.00 -1305.02S -1582.71W 77W ................... 441 67W 520 04W 595 OOW ....... ' .....668 06W 739 803 .... 866. 927 2601.00 2500.00 2701.00 ........ 2600.00 2801.00 2700.00 2901.00 2800.00 .3001.00 ....... 2900.00 3101.00 3000,00 3201,00 3100.00 -1372.88S -1687.20W 98'7 __.~1439.2.1S__~.1790.58W 1046 -1502.36S -1891,65W 1101 -1568,45S -2002.13W 1164 ........ ~1637,27S ....... ~2121,.33W .......... 1234._.' ...... -1716.14S -2253.80W '1318 -1797.42S -2~92-89W 1408 0 0 2 3 6 7 __10 12 23 25 31 4O 47 79 78 78 79 75 ~73 71 64 ...... 63 61 60 59 55 63 _70 ___, 90 DIVIS:ION O~ 011. AN.) D I R E C T I 0 N A L S U R INTERPOLATED VALUES FOR EVEN 100 FEET OF UNION OIL OF CA HELL A-26 WELL COMPLETION RPT v E Y PAGE 2 SUB SEA DEPTH 04/20/72 PREPARED BY SCS TANGENTIAL METHOD _._MEASURED ...... DEPTH TVD SUB SEA __.TOIAL.._CDORDINATES_ LATITUDE DEPARTURE _.MD=yT..V.D ,,, V. ERT ICAL DIFFERENCE CORRECTION ~...~80a ....... 3301,00 .... 3200,00 .... ]~1876,40S ..... ~2535,38W 4989 3401,00 3300-00 -1953,99S -26.75,35W 5175 3501o00 3400,00 -2024.17S ~2815,90W __5360 3601',00. _ 3500,00 -. ~2089,88~_.~_2956'.80W. :~ 5541 3701.00 3600.00 -2169.30S -3084.57W 5729 3801.00 3700°00 -2266.31S -3210.85W 59.37 , _39.01,003800..00_.. m2378.53S__-_~_335~.,49H 6144 4001.00 3900.0'0 -2489'81S -3496.92W 6349 4101.00 4000,0-0 -2600.07S -3638.05W 6741 4301.00 4200.00 -2802.03S -3908.18W 6933 4401.00 4300°00 -2896..14S -4042.59W ,7.120 ~501,00~, ~400.00_..~298.~.235_ ~173,31~ 7305 4601.00 4500,00 -3068-9-0S -4303.70W 7474 4701.00 4600-00 -3143.75S -4416.59W _.1~9~ 9]__ 1588 89 1674 86 1'759 ,_~5~ 1.840 81 1928 88 2036. 2143 107 2248 105 2440 93 25'32 92 26~9. 81 2704 85 2773 69 ~632 7785 7925 8065 8204 8333 8585 8.708 _4801..0.0 .. _ _.4700. O0 ,...~3212.20 S___._-.4518.06 W.. , 4901.00 4800.00 -3276.52S -4614. gTW 5001.'00 4900-00 -3328.60S -4698- 31W 5101.00 ...... 5000..00 _~3380', 67.S_--~47 81.. 64 W _ . 5201.00 5100.00 -3430.765 --4862.31W 5301.00 5200.00. -3472.47S -4931.73W 5401,,0(L~5300..00._ _ ~351~o t8.S~__-~.5001"~.14W .... 55Ol. OO 5 0o.0O -3550' 14s .-5o64.89w 5601.00 5500,00 -3584.72S- -5127o28W .. . . _2831. 5.8. 2884 53 2924 40 ..... 296~ _40 3003 39 3032 29 ~3.06.0 .2_8 '. 3084 24 3107 23 .4, j-/~.I''2 * · ' D i .R~ E.C.-T. I 0 N A.'L S U R ~77~ INTFERP,OLATED VALUES FOR EVEN 1000 FEET OF UNION OIL OF CA WELL A-26 WELL COMPLETION RPT _.MEASURED .... TOTAL .COORDINATES DEPTH TVD SUB SEA LATITUDE DEPARTURE V E Y PAGE MEASURED DEPTH 04/20/72 PREPARED BY SCS ND-T.V~ ..... VERTICAL. DIFFERENCE CORRECTION TANGENTIAL METHOD __1000 ...... 964.66 2000 1665.14 3000 2237.24 __.4000 ............... 2862.59 ..... 5000 6000 __.7000 8000 863.66 -142.01S ......... ..138.18W 1564.14 -583.12S -678.68Wj~ z136.24 - 3o9.77w 2761 · 59___~ 1542.02 S.~._r 1956.35W~/ 3406.92 ~305.92 -1958.58S ~/-2683.64W- 3931.22 3830.22 -2412.31S ~ -3397.72W 4_43.6..2_Y ..... 4.335.21__~29 ZS..5ZS v"--~,088..83 WJ~/_ 5054.17 4953.17 -3356.295 ~'--4742.62W 35 ...... 35.. 334 299 762 428 ..... 1137. .... 3,75~ .. 1593 456 2068 475 __~563__ ' _4~95 2945 382 D I R E C. T I 0 N A L S U R V E Y PAGE iNTERPOLATED VALUES FOR NON SURVEY POINTS MEASURED,.=.. .....~ .............................................................. TOTAL .COORDINATES- MARKER DEPTH 'TVD SUB SEA NW-2 FAULT 3000 223'1.24 2136. NW-ZFAULI 3220 ...... 237_1.93 ............ 2270. 24-6 3745 2699.94 2'598' 26-7 4000 2862.59 2761. 28.6 ......... ~2.72 .... 3022..46 ........ 2.921. 31-8 4920 3364.53 3263. LATITUDE DEPARTURE 24 -1106.46S -1309.77W 93 ........ -1211.1SS =1448.'10W 94 -1438.54S -1789.52W 59 -1542.02S -1956.35W 46 ...... ~.1652.05S ...... ..2146.92W 53 -I9.25.69S -2624.30W 33-6 41.-3 41-8 44-7 C-1 C-2 C-3 C-4 l$ C. 5 C-6 47-5 48-5 48-7 49-4{5.0) ~ 50-3 6190 4'023. 6462 .... 4157' 6590 4222. 6760 4310. 6955 .....4413. 7048 4461. 5210 3519.86 3418.86 -2036.57S -28~2 5.472 ..... 3662.23 ..... 3561.23 ........ ~213!.72S ....... :3038 5558 3710.32 3609.32 -2177.62S -3095 33 3922.33 -2514.62S -3528 90. .....~056.90 ..... 51 4121.51 -2727.84S -3802 71 4209.71 -2811.205 -3921 48 ........ 4342-48 ....... ~29-07.60S ........ -4058 97 4360.97 -2951.18S -4122 7346 4623.18 4522.18 -3087.695 -4332 7490 ........ 4711.36 .......... 4610.36 ......... ~3150.84S ...... ~4427 7920 4997. 8048 5088. 8090 .... 511~. 8220 5213. 8296 5272. .48W .68W .62W .67W .93W .24W .29W .96W .43W .63W .10W 11 4896'11 -3326.58S -4695.07W 41 4987.41 -3374.12S -4771.15W 36 .......5017. 36 ..... _-.3389-72S .......~47.96.12W 71 5112.71 -3436.065 -487'1.14W 77 51'71.77 -3460.70S -49!2.t3W 50-6 .......................... 8408 ...... 5359.81 ......... 525.8.81 ........ ,.--3497.00S .... ~497 2..55W__ STRAY 857'8 5495.33 5394.33 -3548. t8S -5061.35W , 51-6 8656 55'58.83 545'7.83 -3570.14S -5100.97W 51.--..6,J BASE] 8_726. 5615.83 ...... 551,4..83 .... .-._35.89.84S ......... ~513 6.51W J ] ~ j - j " i [ ' ' i - i' '=~' 1 -I i ' JiVISI~DN I i I ' . . -i i. ~vorm No. m~v. 9-~-67 STATE OF ALASKA OIL AND GAS CONSERVATION C MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o~ ~ G,,w,,.L [] o~ water injector 2. NA/~E OF OPEI%ATOR Union Oil Company of Califor~iia .2. OF OPERATOR 909 W. 9th Ave., Anchorage, Alaska 99501 4. LOCATION OF W~L Conductor 50, 1606'N ~ 565'W from SE Corner Section 4, TgN, R15W, SM. SUBMIT IN AP1 NUA{ERICAL CODE 50-133-20230 g. LEASE DESiGI~ATION AND SERIAL NO. ADL 18731 ?. IF INDIA]~, ALOTTEE O1~ TRIBE NAME 8. L.~IT F.~{ OR LEASE NA~VlE Trading Bay State 9. wlgLL NO. A-26 (12-9) A_ND POOL. OR WILDCAT Trading Bay-Middle Kenai "C" 11, SEC., T,, R., 5{., (BOTTO1%{ HOLE om-ncrrv~ Sec. 9, T9N, R15~, 12. PE1RiViIT NO. 71-20 "{3. REPORT TOTAL DI~PTH AT END OF MONTH. CI-IA_NGES IN HOLE SIZE, CASING A_N-D CE1VIF2gTING JOBS INCLUDING DEPTH SET AiWD VOLT0'NIr~ USED, P~'O'P. ATIONS, TESTS ANT) i~ESULTS. FISI-IING JOEhS. JI_FNK IN HOLE A-ND SIDE-TI:lACKED HOLE AND ANY OTHER SIGNIFICANT CI~A.NGES IN HOL~ CONDITIONS, ~IN.G BAY,, STATE A.2.O, APR,IL !9,72 Moved ~ rigged up over conductor 30. SPUDDED TBS A:26 at 10:00 a.m. 4/1/72. Drld $ Gyro-Surveyed 12-!/4" hole to 1048'. 0~ened h01e 't0""17-1/2'"" to 104g"J/ Ran 26 its 15-5/8" K-SS 61# 'buttress csg w/shoe at 1036". 'Float collar at 996'. Cmtd w/SOO sx ClaSs "G" cmt with. 1/2 cu.ft, perlite per sack, 4% gel ~ 1% CFR-2 followed by 200 sx Class "'" --* ' :' ~- . G ~,,c w~ux 1% CFR-2 and 3% CaClg. Good returns' to surface. CIP 9:2,0 a.m. 4/5/72. NU BOP's, tstd ok. Cmtd (top job) 13,3/8" csg, Drld shoe [ i2-!/4' hol~ ~8725'. RU Schlumberger. Ran DIL, comb. density.netttron ~ gamma ray sonic logs. Drld 12~1/4" hole to 8795'. Circ for csg. Ran 53 its 9.5/8" 47# P-110 hUttress csg. ~g w/shoe at 8795', float collar at 8751' DV at ~107'. 'Cmtd 9-5/8" cs~ as follows: 400 sx "G" cmt w/8% gel, 800 Sx ,'G,, with 1/~ cu.ft, perlite per sac~ ~ 4%°gel w/l~ D-31, plus 500 sx "G" cmt. Preceded cmt w/mud sweep. Bumped plug at 3:30 a.m. (btm job) 4/19/72. Float ok. Circ thru DV. Cmtd thru DV w/800 sx Class "G" cmt with 1/2 cu.ft, perlite per sack, 4% gel [ 1% D-31 followed by 150 sx "G" cmt w/l% D-31, 4% gel ~ 1/2 cu.ft, perlite per sack. 370 cu.ft, cmt returns to surface. CIP 8:25 a.m. 4/!9/72. Installed Cameron tbg head [ BOP's. Tstd to 2200 psi ok. ' ....... CO to 8749'. Ran GR*CBL. Perfd four 1/2" hpf w/link DiCone guns from 8698'-8700', Set RTTS at 8537'. ~ed away at 15 cfm.at 270'0#'. Sq. zd w/200 sx "G" cmt w/l% D-31 to 2700#. Approx 175 sx out thru holes. 'CIP sqz Job #1, 5:'00 a.m. 4/22/72. Set RTTS at 8131'~. Perfd 4 hpf 8520 ' .85,22':. Brokedown at 2800# at 2 c~m. sx "G" cmt w/l% D-51 to 2450#. Approx 157 sx cmt thru holes. CIP sqz ~ob # 4/22/72. - ' Sqzd w/200 2.. 11:30 a.m. Perfd 4 holes 7970'-7972' w/R/TS at 7820'. Brokedown at 2000#. 6 cfm rate at 1800#.. Sqzd w/200 sx "G" cmt w/l% D.31. No pressure build up. Over disp holes by 40 cu.ft. Attempt to resqz (sqz #3) but could not get a breakdown at 3200# indicating holes plugged. . ~rm No. P~4 ~v. 9-~-67 STATE OF ALASKA suBMrr ~. API Nm{EmC~ CODE OIL AND GAS CONSERVATION COMMITTEE 6. LEASE DESiGNA~--ION AND SEHIAL NO. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 3, ADDRESS OF OPERATOR 9. WELL NO 4. LOCATION OF WELL 10. FT~LT~ A-ND POOL. OR WILDCAT TBS A-26 (continued) 11. SEC., T., R., 1H., (BO/r'roM HOLE OB0~n~E) 12. P~R2VIIT NO. 13, REPORT TOTAL DEPTH AT END OF MONTH, CI-L~NGES IN HOLE SIZE, CASING A1N-D CE1VIF_2~TING JOBS INCLUDING DEPTH SET ~ VOLU/VIES USED, P~ORATIONS, TESTS A1N-D ,I~ESULTS, FISHING JOB~, JUNK IN HOLE A_ND SIDE-TRACKED HOLE AND A/~Y OTHER SIGNIFICANT CI-IANG~ IN HOL]~ CONDITIONS. rate at 1400 psi, 3 bpm. Perfd 8508'-8520', 2 hpf w/link DiCone jets. Spot 10 bbls mud acid across perfs. Acidized w/480 gals 2-1/2% HCL, 800 gals mud acid, 480 gals 2-1/2% HCL. Pumped acid 1800 psi at 12 cfm. Perfd 8680'-8698' w/2 hpf w/link DiCone jets. Spot 5 bbls mud acid across perfs. Brokedown at 1800 psi, 8 cfm. Acidized 720 gals 2-1/2% HCL$ 1100 gals mud acid, 720 gals 2-1/2% HCL, 1800 psi at 8 cfm followed by 270 bbls wtr. Final rate 1800 psi at 2.1/2 bpm. Set RTTS at 7855'. Injected at S000 BPD rate at 1450#. Ran, profile logging tools. Cont injection at 2050~, at 4400 BWPD. Ran spinner tracer logs. Reset RTTS at 7591'. Injected at 8400 BWPD at 2050# (stabilized rate). Ran profile logs. Ran .junk bskt on Dresser wireline Ran ~ set Brown pemanent production pkr on wrl at 7850' failed. · · Pushed pkr to 8747". Reran tbg w/Dresser-Guiberson hydraulic single pkr ~ Dresser- Guibers~n hydraulic dual pkr. Set Guiberson single Pkr at 7875' & dual pkr at 744I'. Single pkr test ok. Dual pkr failed at !000#. 14. I hereby cert~ that the for,~s~pin.~ is true arui correc% .. , r? J~m ,.~ '~ NOTE--'--R~p;r't'on-t'~iT?oT~' i~"r'equired ~or each cafe.dar month, regard[ess o~ the status o~~eL~i~"" OhS, and must De ~i[ed in ~Pii~ate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed,J f ~ '~ ~ "U,"~.) the .~ o~ suspenateu or ~t p~ nott~y ~ ,of£tee af~y STATE OF ALASKA --T-T-~giG J 50-133-20230 §. OIL AND GAS CONSERVATION COMMITTE - .. -~ ..... .j : . APPLICATION FOR PERMIT T° DRILL, DEEPEN, ADL 18731 DRILL ~ DEEPEN ~ W~LL W~LL O~R ZON~ ~--' 2. NA~ OF OP~TOR Trading ~y Union Oil C~~y of Califo~ia I ,EV ~ ~. ~o. I ~. ~~ ~ o~m~ 909 ~est 9~ Avenue, ~chorage, Alaska 99501 CCN~R. ~. ~OCA~m~O~ ~ Trading Bay-Hiddle Ken~ ~='"~eConductor 30, 1606'N ~ 563'~ fm SE co~er ~[: 4,-~ R13~, ~. "~oLESSC'" ~..o~sc~s~ ~'' ~'' ~o=o~ *A~o~ed~ed.~o-eTop "C" Zone' 2583'S ~ 3702'~ fm surf. loc. 6459' ~,~ 4150"~, 4514 departure ~' SS5°W course. Sec. 9, TgN, R13~, 13. DIST~CE IN ~ILES AND D~ECTION F.%OM NEA~ST TOWN OR'POST OFFICE* 12. ~prox 27 air miles .nor~ ,of~.,Kenai~ Alas 14. BOND INFORMATION: TYPE Statewid~retyand/orNo. United Pacific Insurance Co. B-55372 15. DISTANCE FROM PROPOSED* 'i16'.'i~O, OF ACRES. IN LEASE LOCATION TO NEAREST PROPERTY OR LF-~kSE LINE, FT. 1 ,'700 ' : 840 (Also to nearest drig, unit, if any),, . 3 '{~, DISTANCE FROM PROPOSED LO~A~O~ TO NEAREST WELL DRILLING. COMPLETED, OR APPLID FOR.FT.. . 950,, I 8741'MD ~ 5600'TVD ~o,-t $100,000. O0 17. NO. ACRES ASSIGNED TO THiS WELL ,,( 20. ROTARY:OR CABLE TOOLS roZary 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 2~.-APPROX. DATE WORK WILL START* 101' RT above MSL November 10, 1971 23. PROPOSD CAS.lNG AND CEMENTING PROGRA/VI SIZE OF HOLE SIZE OF CASING} weiGHT. PER FOOT'' 'G~AI)E '! ;":}SETTING DEPTH "' " qUANTITY' 'OF C~MEN~ .:~}. , 17-1/2" ' 15-5/8" " 61~ ~ J-SS 1050' ~t to' surface .... 12-1/4" 9-5/87. 43.5~ N-80 ,7000' ~ 'tie to 15-5/8" csg-25O0~%x 8-1/2" 7" liner 29~" ' N, sO: 6900,"-874t~ 300 sx-tie to u,s/w' cng ilia' SEE ATTACHED. JUL 29 19'/'i[: DIV~;ION OF OIL AND ~A5 ANCHO~GI IH ABOVE SPACE DESCRIBE PRO,POSED PROGRAM: If proposal is to deepen or plug hack, give data on present productive zone and proposed new productive zof~e. If pr(~posal is to drill or deepen direct }0Dally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowot~t preventer program. 24. I hereby certify th~ is True and use) [] YES ~ NO ~. DIRECTioNAL SURVEy REQUIRED DAT~. July 27.,' 19'71 CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: ~TL~ District ,Land'Manag~ APPROVED BY . _ ~ l SEE TRANSMITTAL LETTER A.P.I. ~CAL CODE /~PPROVALDA~ August 12, 1971 TITL~ ~ Chairmmn *See'ln~ructi0", On Reverse Side August 12.. 1971 ATTACttqENT TO P-1 FORM - TRADING BAY STATE A-26 (12-9) Reason For Drilling' To continue development on the southwest flank of the A-2 fault block, Middle Kenai Sands. ~lte well is a proposed Middle Kenai single injector in the "C" interval, and will optimize secondary oil recovery in the "C" zone on the south end of the block. Drilling_ Procedure: 1. Drill 12-1/4" hole to 500' KOP. Directionally drill 12-1/4" hole 300' - 1050'. 2. Open 12-1/4" hole to 17-1/2" hole to 10S0'. 3. Run ~ cement 13-3/8" csg @ 10S0'. Install 12" 3000# BOE. 4. Directionally drill 12-1/4" hole to 7000'+-. S. Run electric logs. 6. Run ~ cmt 9-S/8" csg @ 7000'+- 7. Directionally drill 8-1/2" holg to 8741'TD. 8. Run electric logs. 9. Run ~ cmt 7" liner from 6900' - 8741'. Change over to filtered Inlet wtr. 10. Block sqz for zone segregation top of Middle Kenai "C" interval. 11. Perforate Middle Kenai "C" zone for injection. 12. Set production pkr @ top of "C" zone ~ run single string of 3-1/2" tbg. 13. Install xmas tree & place "C" zone on water injection. * Ta_r. gct Locations: Top of "C!' Z°ne: 2583's ~ 3702'w fm surf. location. 64S9'bD, 41SO'IVD, 4514' departure @ S55°W course. Top Cz7 Sand: 3082'S ~ 4417"W fm surf. location. 7490'MD, 4700'WD, S386' departure @ SS5°W course. Bottom Hole Location: 3S71'S & 5118'W fm surf. location. 8741'MI), ~-600'~, 6241' departure @ SSS~W course. I i TS -9 TD 10,77 / /~, 28 27 '~ . 2_~26 ' ' ~' , ~ % TS-8 / / TS-7~9 ~/ % ~ S-5~ ~/ /' ~ TDIO,~ ~ .v ~,/ ,/ ~-6%' TDli,562 / N ~ / .,.' T~% % / / TS- 4 . ~- / TDI2,353 TO I0,0 ~ 4 lEX TBS ~ TD 9, t04 ADL 18775 A-12 RE A-I9 TD 9£59 A-24 ~TDg190 ? ~- TO TD6627 A- UNION A'I5 ~TD6902 1.000 ~~ ~TO 10,603 TD g066 I A 17 · ' ~" ?6.6 C -7 SAND' ,'~ C-1 SAND TMD 7490 // TMD 6459 .a,~m".,,,.~T~VD 4700 ~' T V D 4150 ./ + TO 7Z60 TD8$10 R 13W ADL 17597 ADL 18776 -..~A -3 TO li,637 R.~j~_~Lv ~ ,.f~,l_ 1873,.~j2ADL 17596 JUL 2 9 19/'~ ~--,, ETB ~1 IDt¥i.~tON. OF OIL AND ~A.5 TD 10 364 ^HClrlOP, AOII T 9 N UNION OIL COMPANY OF CALFORNIA ALASKA DISTRICT , TRADING BAY FIELD COOK INLET, ALASKA LOCATION PLAT TRADING BAY STATE A-26 (12'-9) DATE:, JULY 2t;1971 "= 2000' Lease & Well No. ~;~-~~ CHECK LiST FOR NEW WELL PERMITS 1. Is well to be locate([ in a defined pool ................. A~< 2. Do statewide rules apply ........................ _ __ /~_~._ 3. Is a registered survey plat attached .................. "' 4. Is well located pro~er distance 'from property line ........... ~./~_~: 5. ~s well located proper distance from other wells ............ 6. Is sufficient undedicated acreage avail_able ~n this 7. Is well to be deviated .................. ~ ...... ~~ 8. Is operator tile only a'Ffi::~.:--::~ ~],,~:y .................... 9. Can permit be approYed before t~-~day t~ait ............... 10. Does operator have a bond 'i~'l i:o~'~:e ................... ll. Is conductor string @rovided ...................... 12. Is enough cement used to circulate on conductor and $~rface ...... 13~.,..4ill cement tie in surface and intermediate or production strings 14. Will cement cover all possible productive horizons ........... 15. Will surface casing cover all 'fresh water zones ............. 16. Will surface csg. i~ternal burst equal".5 psi/ft, to next string - 17. Will all casing give adequate safety in collapse and tension ...... 18. Does BOPE have sufficient pressure rating ............... Additional Requirements' A p p r ov.y~l~ ~R~e~co~me nded · ~. TRM ~ o~¢ KLV ~L~ HWK .~-m2,~ ECS