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HomeMy WebLinkAbout181-058 i j/ Marathon Alaska Production L• • r \\ J Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 March 30, 2012 Cathy Foerster RECEIVED Alaska Oil & Gas Conservation Commission L , 333 W 7 Ave 0 3 2 082 Anchorage, Alaska 99501 - \laska Oil Gas Cons. Anchorage Commission Reference: 10 -404 Report of Sundry Well Operations G 0 Field: Cannery Loop Field 0 1 Well: Cannery Loop Unit #3 Dear Ms Foerster, Sc_ANNE APR 0 5 2012 Attached for your records is the10 -404 Report of Sundry Well Operations for CLU -3 well. This report covers the MIT testing work performed in preparation for gas injection into the CINGSA Gas Storage project. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, iitYv.A-d ( 9" • 6 ato- Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File MIT Test form Kenai Well File (2) KJS STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon H Repair Well H Plug Perforations H Stimulate H Other U MIT Test Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Alaska Production LLC Development Q Exploratory - 181 - 058 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 - 1949 - 50 133 - 20340 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE ' Cannery Loop Unit #3 9. Field /Pool(s): Cannery Loop Unit / Beluga Pool 10. Present Well Condition Summary: Total Depth measured 11,125' feet Plugs measured 6,048' feet true vertical 10,552' feet Junk measured NA feet Effective Depth measured 6,048' feet Packer measured 5,718' feet true vertical 5,718' feet true vertical 5,411' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 85' 20" 114' 114' 1,530 psi 520 psi Surface 2,666' 13 -3/8" 2,695' 2,627' 3,090 psi 1,540 psi Intermediate 8,101' 9 -5/8" 8,130' 7,683' _ 6,870 psi 4,750 psi Production 3,342' 7" 11,125' 10,552' 8,160 psi 7, psi Liner RECEI Perforation depth: Measured depth: 5,788' - 5,828' feet RECEIVED L APR 002012 True Vertical depth: 5,476' - 5,513' feet , laska O Cas Cons. Commission Tubing (size, grade, MD & TVD): Production 3 -1/2" N -80 5,768' Al raj 5,458' TyD SSSV: NA Packers and SSSV (type, MD & TVD): Packers: Baker DB 5,718' MD 5,411' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Performed MIT test in preparation for the CINGSA gas storage project. Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure I Prior to well operation: 0 0 0 - - Subsequent to operation: 0 0 0 - - 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil ❑ Gas U WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: j 312 - 024 �/ Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature <J4r1..%4._, . . VIII) Phone (907) 283 -1371 Date March 30, 2012 R DMS APR 0 4 20121C- ` -i i__- Form 10 -404 Revised 10/2010 * / Submit Original Only • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regqaalaska.00v: doa. aoocc.prudhoe.bay(a)alaska.clovi phoebe.brooks(a)alaska.gov tom.maunder(8alaska.ciov OPERATOR: Marathon Oil Co. FIELD I UNIT I PAD: KGF /Cannery Loop DATE: 03/01/12 OPERATOR REP: Mike Sulley AOGCC REP: Matt Herrera Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CLU 3 Type Inj. NA TVD 5,411' Tubing zero zero zero zero Interval 0 P.T.D. 181 -058 Type test P Test psi 500 psi Casing 70 550 550 550 P/F P P Notes: Took 35 gas to fill. Recovered 35 gals. OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) This well is shut in. Testing 3 -1/2 x 9 -5/8" annulus. Test was performed in accordance w/ Storage Injection Order NO. 9, Rule 5 Sundry Number 312 -024 Form 10 -426 (Revised 06/2010) MIT CLU - 03 - 12.xls • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March 12, 2012 TO: Jim p C � 3i . 2 P.I. P. Supervisor I 1 I ! - z., - SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 03 FROM: Matt Herrera CANNERY LOOP UNIT 03 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry Comm Well Name: CANNERY LOOP UNIT 03 API Well Number: 50 - 133 - 20340 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH120307103331 Permit Number: 181 - 058 - Inspection Date: 3/1/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03 - Type Inj. N 'TVD IA 70 550 - I 550 550 - PTD 1810580 - TypeTest SPT Test psi 500 ' OA _ I Interva °T R - P/F P . Tubing 0 0 0 0 - i Notes: Monobore completion NO OA. MIT performed for CINGSA order no. 9 312 -024. - JU . L , \`. Monday, March 12, 2012 Page 1 of 1 • • SEAN PARNELL, GOVERNOR �T ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin Skiba Regulatory Compliance Representative Q5 Marathon Alaska Production, LLC PO Box 1949 �D Kenai, AK 99611 fa ..ANNE :� FEB 4 201 Re: Cannery Loop Unit, Beluga Pool, Cannery Loop Unit #3 Sundry Number: 312 -024 Dear Mr. Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this l2day of February, 2012. Encl. Marathon Alaska Production LLC ■ ``.,l /, Alaska Asset Team P.O. Box 1949 M Coil Marathon L,ii1 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 January 19, 2012 ` F C F11 D Mr. Daniel Seamount JAN 2 !. ?112 Alaska Oil & Gas Conservation Commission 333 W 7 Ave sssthl�l�s.Oln�issi� Anchorage, Alaska 99501 "' �iit' Reference: 10 -403 Application for Sundry Approvals Field: Cannery Loop Field Well: Cannery Loop Unit #03 Dear Mr. Seamount, Submitted for your approval is the10 -403 Application for Sundry Approvals for CLU -03 well. Marathon proposes to perform a Mechanical Integrity Test of the wellbore to comply with the Storage Injection Order No. 9, Rule 5: Demonstration of Mechanical Integrity. Please find attached the Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Mechanical Test Plan which provides a summary and background for the test, the details that relate to the subject well, and a current wellbore schematic, depicting the Sterling C1 interval depths. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, '''' ‘..12,0-W . 9- , .5 , Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC CINGSA SIO 9 Mechanical Integrity Test Plan Houston Well File Current Well Schematic Kenai Well File (2) KJS F fl.� ALAS IL AND GAS CONSERVATION COMMISS '` JAN ?, 3 2 012 APPLICATION FOR SUNDRY - tas'gui L1 & Lin bulls. k:01'tin iSSIMI 20 AAC 25.280 Type of Request: Abandon g ❑ ❑ Repair ns ap 1. T ved program ❑ yp q ❑ Plug for Red Perforate New Poo Re air well ❑ hag Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Perform MIT Test " ID 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development 0 Exploratory ❑ 181 -058 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20340 -00 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No D Cannery Loop Unit #3 9. Property Designation (Lease Number): 10. Field / Pool(s): FEE • Cannery Loop Unit / Beluga Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,125' • 10,552' - 6,048' 5,718' 6,048' NA Casing Length Size MD TVD Burst Collapse Structural Conductor 85' 20" 114' 114' 1,530 psi 520 psi Surface 2,666' 13 -3/8" 2,695' 2,627' 3,090 psi 1,540 psi Intermediate 8,101' 9 -5/8" 8,130' 7,683' 6,870 psi 4,750 psi Production 3,342' 7" 11,125' 10,552' 8,160 psi 7,030 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,779' - 5,834' 5,468' - 5,519' Production 7" N - 80 5,768' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): SSSV: NA Packers: Baker DB Packers: 5,718' 5,411' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 " Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 1 , 2012 Oil ❑ Gas 0 • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature iv Phone (907) 283 -1371 Date January 19, 2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\ Z- C04 Plug Integrity ( BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: a dd psi /'4 17 Subsequent Form Required: / 0- 0(-( APPROVED BY /) / Approved by: COMMISSIONER THE COMMISSION Date: j- /1 a, 2-11- - 1■ 0 R 1 G 1 N A OR1GINAL FEB 14 2012 Qr ' 7 . t2- Form 10 -403 Revised 1/2010 Submit in Duplicate • Cook Inlet Natural Gas Storage Alaska, LLC Proposed Mechanical Integrity Test Plan Cannery Loop Sterling C Gas Storage Pool Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) requested by application dated July 27, 2010, a storage injection order from the Alaska Oil and Gas Conservation Commission (AOGCC) authorizing injection for the underground storage of natural gas in the Sterling C Gas Storage Pool of the Cannery Loop Unit. The AOGCC held a public hearing on October 19 -20, 2010 during which CINGSA presented oral and written testimony concerning the project. By Order, the AOGCC issued Storage Injection Order No. 9 (SIO 9) dated November 19, 2010, granting CINGSA the authority to commence the injection of gas for underground storage subject to certain Conclusions and Rules, all as more fully outlined in SIO 9. Two of the key requirements imposed on CINGSA as a condition of SIO 9 are that CINGSA 1) demonstrate the mechanical integrity of all storage injection wells and existing pool wells before injection commences (Rule 5 Demonstration of Mechanical Integrity), and 2) maintain surveillance of operating parameters for storage and offset wells to provide continued assurance that gas remains confined to the Sterling C Gas Storage Pool (Conclusion 8). Following, is the methodology CINGSA proposes to employ to demonstrate the mechanical integrity of all existing pool wells and maintain continued surveillance of the Pool to assure that gas remains confined to the Sterling C Pool. All new gas storage wells will be tested in accordance with 20 AAC 25.412 (c)(d). CINGSA proposes to satisfy the requirements of Conclusion 8 and Rule 5 of SIO 9 through routine monitoring of the annulus pressure of existing wells, and via pressure testing the annulus of certain wells to demonstrate their mechanical integrity, plus the tubing string of certain other wells. Table 1 provides a summary of the scope of CINGSA's proposed measures to satisfy the requirements of Conclusion 8 and Rule 5. The rationale for monitoring pressure of certain annuli and performing a mechanical integrity test is more fully summarized for each individual well below. Table 2 provides a depth reference to the Sterling C1 interval, from Sterling C1 Top to U. Beluga Top, by well. Routine monitoring and recording of annulus pressure will help identify whether any gas may be leaking from the Sterling C Pool or other formations. CINGSA proposes a monthly monitoring and reporting frequency to satisfy the requirements of Conclusion 8. CINGSA proposes to conduct a mechanical integrity pressure tests on the annulus of the wells listed in Table 1 to satisfy the requirements of Rule 5. CINGSA proposes a maximum test pressure of 500 psi for 30 minutes since most of the wells are not completed with tubing set on a packer, and thus, are not in the same configuration contemplated in 20 AAC 252. • • Table 1 Proposed Routine Monitoring and Mechanical Integrity Test Plan Cook Inlet Natural Gas Storage Alaska, LLC Well Name Current Status Annulus for MIT Routine Monitor Annulus CLU 1RD Producing 41 2 x 7 4 1/2 x 7 and 7 x 9 5/8 g / e 145 CLU 3 / Inactive 3 1/2 x 9 5/8 3 1/2 x 9 5/8 7 f s4. CLU 4 Inactive 3 1/2 x 13 5/8 3 1/2 Tbg, 3 1/2 x 13 5/8, and 13 5/8 x 20 CLU 5 Inactive 3 1/2 Tbg x 9 5/8 3 1/2 Tbg, 3 1/2 x 9 5/8, and 9 5/8 x 13 3/8 CLU 6 P & A Sterling C 4 1/2 Tbg 41/2 tbg and 4 1/2 x 7 CLU 7 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 8 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 9 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 10 Planned P & A 3 1/2 Tbg and 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 11 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 12 P & A'd Sterling C None 9 5/8 Csg Table 2 Cannery Loop Wells, Sterling C interval, Sterling C1 Top to U. Beluga Top Well Name Sterling C depth interval, MD Sterling C depth interval, TVDSS CLU 1RD 5815 -6155 -4927 to -5155 CLU 3 5313 -5574 -4963 to -5205 CLU 4 5171 -5409 -4971 to -5198 CLU 5 6063 -6300 -4856 to -5081 CLU 6 7782 -8114 -4876 to -5099 CLU 7 7700 -7965 -4858 to -5095 CLU 8 6690 -6945 -4871 to -5101 CLU 9 5942 -6195 -4860 to -5102 CLU 10 5372 -5614 -4883 to -5125 CLU 11 6281 -6537 -4876 to -5113 CLU 12 7264 -7522 -4920 to -5158 • • CLU 3 CLU 3 is currently completed to the Beluga B2 interval via a 3 -1/2" tubing string w/ a packer at 5718 ft MD. Note previously squeezed perfs at 5422 through 5520 ft MD, above packer at 5718 ft MD. Sterling interval 5313 -5574 ft MD. Proposed Annuli to configure for routine pressure monitoring: • 3- 1/2 "x9 -5/8" tubing head • Completion records indicate the 9 5/8 inch casing was cemented back to surface (10 Bbls returns), thus monitor annulus pressure on the 9 5/8 x 13 3/8 would be meaningless. Proposed Mechanical Integrity Test Procedure: • Perform a 500 psi pressure test of the 3 -1/2" x 9 5/8" annulus, being mindful of the low pressure on the inside of the tubing and of collapse potential above the packer set at 5718 ft MD. CINGSA proposes a 30 minute test duration with no more than a 10 percent change in pressure during that time interval being required for a valid test. • The proposed pressure test will apply an approximate differential of 2336 psi at 5714 ft MD/5394 ft TVD, per the following assumptions: an approximate 500 psi internal tubing pressure at TVD; a fresh water hydrostatic gradient in the annulus, and the 500 psi of applied surface pressure. • Testing of the 9 5/8" x 13 3/8" annulus is not recommended because the 9 5/8" string was cemented back to surface. 0 • Field: Cannery Loop Well: CLU 3 ( NJ. Pad: CLU 3 API: 5-133-20340 Marathon Well Spud Date: 5/26/81 Current Completion Run Date: 02/01/1988 ir/ RKB -GL: 64' ---II (� Wellhead Details: (Cameron) GL Elevation: 35' 3 1/8" 5000psi single tree KOP: 1000' MD 3 1/2" 5000psi single tbg hgr 3 Y." EUE top & bottom Max Deviation: 25 at 3600' MD 10" 5000psi bottom flange Annular Fluid Details: Surf- by -Cond: Type "G" cement Prod -by -Surf: Type "G" cement Tub -by -Prod: Packer fluid Perforation Details: Conductor: 85' MD 20 ", 94 # /ft, Grade: H -40, Conn: N /A, Re servoir: Sterling Squeezed Cement: N/A (Driven) 5112' 5111' ELM squeezed 8/19/81 20" Hole, TD 85' MD 5422' 5135' ELM squeezed 9/12/81 5158' 5470' ELM squeezed 9/12/81 Surface: 2695' MD 5508' 5520' ELM squeezed 9/10/81 / 13 -3/8 ", 61 # /ft, Grade: K -55, Conn: BT Cement: 1210 sx "G" + 2% CaCl2 & 2.5% gel followed by 300sx Reservoir: Beluga B1 Squeezed "G" + 2% CaCl2 5565' 5567' ELM squeezed 8/19/81 _ ___.- PIT: 11.4 EMW 5589' 5594' ELM squeezed 9/7/81 / Sterling C1 171/2" Hole, TD 2730' MD, TOC: surface G^ 01 5603 ELM ^'' Q M squeezed 8/18/81 // J Interval: 5313 -5574 Production /Intermediate: 8130' MD Reservoir: Beluga B2 Current Cmpl • 9 -5/8 ", 47 # /ft, Grade: N -80, Conn: BT 5779' -5781' ELM squeezed 8/18/81 Cement: 750sx "G" + 3% KCI & 2.5% gel (13.Oppg) followed by 5788' -5796' ELM 2 1/8", 4spf, 0 \ t c .. 1255sx "G" + 5% KCI (15.9ppg) 5796' -5798' ELM squeezed 8/17/81 ` ,� __s1 IA PIT: 12.6 EMW 5804' -5812' ELM squeezed 9/6/81 121/4" Hole, TD 8130' MD, TOC: Surface 5818' -5828' ELM 2 1/8 ", 4spf, 0 297(=z 5832' -5834' ELM squeezed 8/17/81 \ Production Liner: 7783 - 11125' MD 7 ", 29 # /ft, Grade: Conn: BT, Reservoir: Beluga B3 Squeezed Cement: 1000sx "G" + 5% KCL 6091' 6093' ELM squeezed 7/16/81 8 -1/2" Hole, TD 11125' MD, TOCE ?' MD 4 Reservoir: Beluga B4 Squeezed Production Tubing: 3 1/2 ", 9_2 # /ft, Grade: N -80, Conn: BT 6156' 6172' ELM squeezed 8/31/81 Set @5768' MD, Special Clearance- 2.75" ID, Drift: 2.685" 6175' 6177' ELM squeezed 8/18/81 ... INN.. Packer Set @ 5718' MD Baker "DB" Reservoir: Beluga B6 Squeezed Completion Equipment: 7187' 7189' ELM squeezed 8 7 2.75" Otis 'XA' sliding sleeve at 5687' MD 7192' 7202' ELM squeezed 8/29/81 ` t 3.00" Baker "DB" packer @ 5714' MD 7228' 7238' ELM squeezed 8/29/81 2.875" Otis 'X' nipple at 5736' MD 7216' 7218' ELM squeezed 8/13/81 3.00" Re-entry guide (5.25"x4.375" OD) @5768' MD J Reservoir: Upper Tyonek T1 Squeezed Cement retainer, 6050' MD 9372' 9371' ELM squeezed 7/23/81 Cement retainer, 7092' MD 0386' 9100' ELM squeezed 8/12/81 0408' 9410' ELM squeezed 7/23/81 "------ Cement retainer, 9280 ft MD Cement retainer, 9775 ft MD Reservoir: Upper Tyonek 94 -9 Squeezed Cement retainer, 10020 ft MD 9898' 9900' ELM squeezed 7/22/81 Cement retainer, 10391ft MD 9902' 9915' ELM squeezed 8/9/81 9936' 9938' ELM squeezed 7/21/81 PBTD: 6048'MD 1/27/88 Reservoir: Deep Tyonek D -2A Squeezed Last Tag: 6057'MD 4/21/88 2.685" GR 10128' 10148' ELM squeezed 8/6/81 "•••••....—.....--- Reservoir: Deep Tyonek D -3A Squeezed 10501' 10512' ELM squeezed 8/6/81 10530' 10534' ELM squeezed 8/4/81 10516' 10531' ELM squeezed 8/4/81 Schematic Updated: 11/9/2011 Updated By: James Ostroot Unocal Oil & Gas ~ n Unocal Corporation R O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL August 1, 1989 Craig K. White District Exploration Geologist. Alaska District Hr. Lonnie C. Smith Alaska Oil & Gas Conservation Commission 3001 Rorcupine Drive Anchorage, Alaska 99501 Dear Hr. Smith: As requested by the A.O.G.C.C. through A.O.G.A., we 'are providing replacement copies of reproducible (sepia) logs for Unocal-operated wells, as follows: Canoe Bay Unit #1 (Pure Oil Co.) Cannery Loop Unit #1 Cannery Loop Unit #2 Cannery Loop Unit #3 Clam Gulch Unit #1 Grayling 1-A Kasilof Unit #1 Kenai Unit 41-18 Knik Arm #1 Knik Arm St. #1 Kustatan #1 Kustatan #lA Ninilchik #1 Pittman #1 Rretty Creek Unit #2 (Chevron) Trading Bay Unit 6-30 5" E-log 2" E-log 5" BHC, 5" Density~E ~oG~ 5" BHC ~ .% 5" Density, 2" DIL 2" E-log 2" E-log Hudlog 2" E-log 2" E-log 2" E-log 2" E-log 2" Sonic '-- ~ ~e~ 5" Microlog 5" CNL, 5" Neutron Ct. Rate GR-Neutron (tie in), CET log 2" & 5" Sonic, 5" Density West Trading Bay St. #1 2" & 5" BHC, 2" & 5" E-log · Rlease return one copy of this letter in acknowledgement of your receipt of this data. / ( /Craig K. White~ ~ ~i.~ ~ ~ ~]~ ~ ?~ , I~ STATE OF ALASKA ALi~,..,,~ OIL AND GAS CONSERVATION COMMI . REPORT OF SUNDRY WELL OPERATIONS ii-Operations performed: Operation shutdown __ Stimulate ~ ' Plugging __ Perforate ~ Pull tubing __ 2. Name of Operator / 5. Type of Well: Union Oil Company of California (UNO~AL) Development__~.X 3. Address I Exploratory_ Stratigraphic __ P.O. Box 190247, Anch, Ak., 99519-02~7 Service__ 4. Location of well at surface 2790' FNL, 2440' FWL, Sec. 4, TSN, RllW, S.M. At top of productive interval 2180' FNL, 906' FWL, Sec. 4, T5N, RllW, S.M. At effective depth 2150' S; 805'E from W Corner, Sec. 4, T5N, RllW, SM Alter casing __ Repair well __ Pull tubing __ Other __ At total depth 1574' FNL, 573' FEL, Sec. 5, T5N, RllW, S.M. 6. Datum elevation (DF or KB) GL 35' MSL 7. Unit or Property name Cannery Loop Un£t 8. Well number CLU #3 9. Permit number/approval number 8158 - ~--~_.. 10. APl number 50-- 133-20340 11. Field/Pool feet Cannery Loop Beluga 12. Present well condition summary Total depth: measured true vertical 11,125' feet 10,564' ~et Plugs (measured) Effective depth: measured true vertical 6,048 ' feet 5702' feet Junk(measured)CHT & BRZDGE PLUGS Casing Structural Conductor Length 85' 2,695 ' Size Cemented Measureddepth 20" Driven 85' 13 5/8" 1,510 SX 2,695' ~ueverticatdepth 85' 2,627' Surface Intermediate Production 8,130' 9 5/8" 2,005 SX 8,130' 7,688' Liner Perforation depth: 3,342 ' measured true vertical 7" 1,000 SX 5,788'-5,796'; 5,818'-5 828' 5,466'-5,474'; 5,488'-5,497' 1/2", 9.2# N-80 0-5,768' Baker "DB" PKR $ 5~718' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) XYLENE TREATMENT 5788'-5796'; 5818'-5828' 7,783'-11,125' 73"33' - 10,544' RE6EIVED AtasJ~ Oil.& 8as Cons..Commission Treatment description including volumes used and final pressure 2838 GALS XYLENE ~ 4500 PSI 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 300 800 PSI Subsequent to operation --- 1800 --- 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ..X. Oil ~ Gas X Suspended "17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~oy D. Roberts Title Fnvirnnm~nt~l Fnginfifir Form 10-404 Rev 06/15/88 Service 800 PSI Date ,11. ./11/8 ~ SUBMIT IN DUPLICATE (~ UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO, LEASE Cannery Loop W E L L NO CLU tI:~ FI ELD, Cannery Loop Beluga DATE 7123188 8/17/88 E.T.D. 6,048' 6048' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Moved in rigged up Otis coiled tubing unit. Pressure tested coiled tubing unit and BOPE to 2500 PSI, ok. Made up 1.80" jet nozzle and ran in hole to 6048 ETD. Circulate with 88 bbls of 6% KCL and XC polymer. Set tubing with Nitrogen at llO0 SCFM and 2550 PSI, partial to full returns. Rulled coiled tubing to 5830' holding 700 PSI tubing pressure on choke and spot Xylene treatment 3000 gallons total. Containing 2838 gallons Xylene, 150 gallons N-Flow 40 and 12 gallons NE-18 across perforations 5788'-5796' and 5818'-5828' at one BRM and 4500 RSI. Displaced coiled tubing with 16 bbls of KCL water, treatment in place at 1600 hours. Pulled out of hole with coiled tubing unit and shut in well for 24 hour soak with 2000 RSI tubing pressure. .Attempted to flow well without success. Rigged up Schlumberger (E) 3et-3, 2-1/8" perforating guns, 4 SPF at zero degrees. Re-perforated 5788'-5796' and 5818'-5828' overbalanced. RECEIVED NOV 1 8 ]gS~ ,A~aska 0il & Gas Cons. Commission Anchorage A .,A OIL AND GAS CONSERVATION COMM . .)N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging ~ Time extension __ Stimulate -.X.- Change approved program __ Pull tubing ~ Variance __ Perforate X-- Other __ 2. Name of Operator / 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development X GL 35' HSL Exploratory ~ Stratigraphic ~ 3. Address [ 7. Unit or Property name P.0. Box 190247~ Anch: Ak. ~ 99519-02/-~7 Service__ Cannery Loop Unit 4. Location of well at sudace 2790' FNL, 2440' FWL, Sec. 4, TSN, RllW, S.M. At top of productive interval 2180' FNL, 906' FWL, Sec. 4, T5N, RllW, S.M. At effective depth 2150' S; 805'E from West Corner, Sec 4, T5N, At total depth 1574' FNL~ 573' FEL~ Sec. 5~ T5N~ RllW~ S.M. 12. Present well condition summary Total depth: measured 11,125 ' feet true vertical l0,564 ' feet 8. Wellnumber CLU #3 9. Permitnumber 8158 10. APInumber 50-- 133-20340 11. Field/Pool Cannery Loop Plugs (measured) feet Beluga Effective depth: measured 4., 048 ' feet true vertical 5702_ ' feet Junk (measured) CMT & BRIDGE PLUGS Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth Size Cemented Measureddepth 85' 20" Driven 85' 2,695' 13 5/8" 1,510 SX 2,695' 8,130' 9 5/8" 2,005 SX 8,130' 3,342' 7" 1,000 SX measured 5,788'-5,796'; 5,818'-5,828' true vertical 5,466'-5,474'; 5,488'-5,497' Tubing (size, grade, and measured depth) 3 1/2", 7,783'-11,125' 9.2# N-80 0-5,768' ~ueve~icaldepth 85' 2,627' 7,688' 7333" .- -t0,544 Packers and SSSV (type and measured depth) Baker "DB" PKR ¢ 5,718' 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: ~, July 23, 1988 16. If proposal was verbally approved 7- 21-88 Oil __ Name of approver Russ Dougtas Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SigdeC7 Roy D. Roberts Title Environmental Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Gas ..Z.. Suspended __ Date 11/11/88 I Approval N o. F... ~:;~,~..--- Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- //" ¢~ Approved Copy Returped ~, ORIGINAL SIGNED BY //.. ~. ¢~ Appro~ved by order of the Commission~NNIE C, SM !TH Commissioner Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE CANNERY LOOP UNIT WELL No. 3 PROCEDURE' 1. MIRU over CLU-3 with 1 1/4" coiled tubing unit and BO foam N2 unit. 2. Pressure test all surface lines to + 2500 psi. 3. Function test BOP system on Coiled tubing unit. 4. RIH with Dynadrill and mill on 1 1/4" tubing and tag top of fill. (4/21/88 tag at + 6048'). 5. Attempt to clean out with Dynadrill to ETD of 6048'. 6. POH with Dynadrill and RIH with jetting nozzle (wash tool). Switch surface lines to Xylene. 7. Repressure test lines if needed to ~ 2500 psi. 8. Work coiled tubing unit across perfs F/5788'-5828' spotting Xylene mixture. 9. Attempt to bullhead this mixture into formation w/N2 or field gas. 10. POOH with coiled tubing unit and shut-in well for 24 hours. 11. RIH with coiled tubing unit and clean out wellbore with KCL-Gel system. 12. Blow well dry with N2 if needed. 13. POOH with coileO tubing unit and return well to production. Classification of Service Well 1. Status of Well . OIL [] GAS F~ SUSPENDED [] ABANDONED [] SERVICE [] 2. Name (~'f Operator 7. Permit Number Union Oil Co. of California 81-58 ._ 3. Address 8. APl Number P.O. Box 190247 Anchorage, AK 99519 s0-133-20340 , 4. Location of well at surface 9. Unit or Lease Name 2790' FNL, 2440' FWL Sec. 4 T5N, RllW, S.M. Cannery Loop Unit At Top Producing Interval ~ ' 10. Well Number 2180' FNL, 906' FWL, Sec. 4, T5N, RllW, S.M. CLU #3 At Total Depth 11. Field and Pool 1574' FNL, 573' FEL, Sec. 5, T5N, RllW, S.M. Cannery Loop 5. Elevatipn ~n,~f~et (indicate KB, D~, etc.) 6. Lease Designation and Serial No. Beluga __'r 3o Fee Lease - Fredrickson , 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. oi Completions 5-26-81 7-12-81 2-1-88 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. P'lugBackDepth(MD+TVD) 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of Permafrost 11,125'; 10,564'v ! 6048'; YES[X] NO[] N/A feet MDI N/A 22. Type Electric or Other Logs Run CUL/CCL/CR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM . HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" , 94 H-40 0 85 ' Driven - 13,3/81- 61 K-~5 ,, 0 2695' 17.5" 1510SX - ~-~ 5/~8'' 47 N-80 0 8130' 12.25" 2005SX - . 7" . 29 N,80 7783' 11125' 8.5 1000SX - 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (M'D) PACKER SET (MD) 5788'-5796' MD; 5466'5474; VD 3-1/2" 5734' 5714' 4 Hpf @ 1/2" each 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5818'-5828' MD; 5488'-5497' VD DEPTH INTERVAL (MD) AMOUN~- & KIND OF MATERIAL USED 4 hpf @ 1'/2" ~each N/A · 27. PRODUCTION TEST , , Date First Production Method.of Operation (Flowing, gas lift, etc.) 2/25/88 ' -Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 2/2/88 24 TEST PERIOD I~ · OIL'-BBL GA$-MC'F WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 1600 psi, 24-HOUR BATE I~ "-- .. 5.3 MtV~/ D 12 BW~D :28. CORE DATA , ,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' .... A~, STATE OF ALASKA ~( ~ ALASK ,LAND GAS CONSERVATION C -,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 4 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME / GEOLOGIC MARKERS 30. FORMATION TESTS .. Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. MEAS. DEPTH TRUE VERT. DEPTH 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Envirn. Enqr. Date,, 5/26/88 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water.supply for injection, observation, injection for in-situ combustion. ,, Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Itq~. 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in iteml i6, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each' additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. · Item 28' If no cores taken, indicate "none". O~ ,~O. OF CALIFORNIA UNION D LLING RECORD PAGE NG. LEASE CANNERY LOOP UNIT CLU #3 CANNERY LOOP WELL NO. FIELD_,. DATE 1988 CLU 3 1-19 1-20 1-21 1-22 1-23 1-24 1-25 1-26 1/27 1/28 1/29 1/30 1/31 2/1 0470N E.T.D. TD. 11,125 ' 0' 11,125' 0' 11,125' 0' 11,125 ' 52' 11,125' 3,410' 11,125' 5,300' 11,125' 5,502' 11,125' 5,729' 11,125' 6,048' 11,125' 6,048" 11,125' 6,048' 11,125' 6,048' 11,125' 6,048' 11,125' 6,048' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Be~inAFE ~371122 @ 0001 Hrs, 1/19/88. Rig on turnkey move. Skidded substructure from CLU #4 to CLU #3 with derrick in air leaving remainder of rig in place. Continue to rig up. Began cleaning mud pits. COntinue turnkey rig move. Accepted rig @ 1200 hrse 1/20/88.' Removed 11", 5000 psi blind flange with bleeder valve from DCB spool. Cleaned cement from spool. Installed BOPE (13-5/8", 5000 psi: Single gate with 5" rams, mud cross, double gate with VBR's on bottom and blind rams on top, annular preventer). Installed kill line, choke line, spool and rotating head. Installed flowline, vent and choke house lines. Attempted to test BOPE but single gate would not function. Worked on gate in place then nippled down stack to change out gate. Rig ~154 off payroll while changing out lower single gate ram. Begin BOPE test and put rig back on payroll @ 1600 hrs. Tested all BOPE to UOC specifications. Made up 8-1/2" bit. RIH and tagged cement at 30'. Cleaned out hard cement to 52'. Continue to cleanout cement to retainer @ 156'. Drilled retainer; no gas under retainer. POOH. Remove rotating head and installed bell nipple, flowlineand trip tank lines. Installed rotary drip pan. RIH to3410' pushing junk and circulating out thick heavy mud in stages. Continue RIH to retainer @ 5294' circulating out thick heavy mud in stages. Tested casing to 1000 psi. Drill on junk and retainer 5294' 5300'. Trip for bit. Continue to drill retainer @ 5300'. Drilled retainer @ 5300' and cleaned out cement to retainer @5496'. Tested casing to 1000 psi - OK. Drill retainer 5496-97'. Trip for bit. Drilled retainer @ 5497'. Cleaned out cement to 5502'. Cleaned out hard cement from 5502' to 5729'. Tested casing to 1000 psi. Tripped for 9-5/8" casing scraper. Circulated and centrifuged water base system for disposal with bit @ 5729'. Cleaned surface pits and began filling same with 68 pcf LVT oil mud from CLU 94. Pumped oil mud spacer followed by LVT oil mud. Cleaned out cement from 5729' to 5752'. POOH and laid down scraper and boot sub. Picked up (6) 6-1/4" DC and RIH. Drilled cement from 5752' to 6048'. Circulate and condition. POOH. Ran CNL-GR-CCL from 6048'-5000'. Tested BOPE. Made up TC perforating assembly and RIH picking up tubing. Rigged up surface equipment and tested to 4500 psi. Ran GR log to correlate guns to DIL. Displaced tubing w/N2, then bled pressure off to 2040 psi BHP. Dropped bar and fired guns (5788-5796' and 5818-5828'). Tested well at 5.3 MMSCF and 1650 psi. tubing pressure. Terminated test, killed well and POOH. P. U. permenant packer and RIH to 5714'. Set and tested packer. POOH laying down D.P. P.U. 3-1/2" production tubing and RIH. Stabbed into packer. Nippled down BOPE and nippled up tree. Opened "XA" sleeve and displaced drilling mud with packer fluid. Displaced the tubing with N2 and closed "XA" sleeve. Began flowing well with UNOCAL testers. Flowed well at stabilized rate of 5.3 MMSCF and 1600 psi (10-14 BWPD). Set BPV. Released rig at 1800 hours for turnkey rig move. "'"' ' ¢ .... STATE OF ALASKA " ' (, ,_AsKA OIL AND GAS CONSERVATION % APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F"i Suspend .r-1 Operation Shutdown [] Re-enter suspended well Time extension [] Change approve~ program [] Plugging [] Stimulate [] Pull tubing ,q Amend order J~ Perforate [] Other 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 4. Location of well at surface 2790'S & 2440' E of NE Cot., Sec. 4, TSN, RllW, SH At top of productive interval At effective depth At total depth 5. Datum elevation (DF or KB)~'~ GL 35 ' HSL~"~et 6. Unit or Property name Cannery Loop Unit 7. Well number CLU #3 8. Permit number 81-58 9. APl number 50-- 10..Pool~~'~-20340 11. Present well condition summary Total depth: measured feet true vertical 11,125 feet Effective depth: measured 150 feet true vertical .1.50 feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 85 ' 20" Surface 2695.10 13 3/8" Intermediate 8130.17 9 5/8" Production Liner 3342.06 7" Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12.Attachments Cemented Driven 1510 sx 2005 sx 1000 sx Measured depth 85' 2695.10 8130.17 11125.01 [CF!V[D 0 8 1986 Description summary of proposal Detailed operations program [] ~ue Vertical depth 85' 2626.28 7687.71 ..... 10564.65 BOP sketc~ 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby, ¢,ert.i.%U~aJ. tho foregoing is true and correct to the best of my knowledge Signed R . ' rts..,,( Title Conditions of approval Approved by ,BY [¢~. J;, SJlTil Form 10-403 Rev 12-1-85 /. / I~nvironmental Engineer Date ?/?~/~ ____.._ I~'" Commission Use Only Notify commissioq s/o representative may witness J Approval N~,~/~ C] Plug integrity ~.~BOP Test [] Location clearance! ,Approved Co¢*.7' by order of ,he commission Date{~::)~~' Submit in triplicate APPLICATION FOR SUNDRY APPROVAL CANNERY LOOP UNIT # 3 12. Description Summary of Proposal l® . 5. 6. 7. 8. Move rig into existing CLU #3 pad, and rig up. Install and test 80RE. Clean out drillable retainers at 150', 5300', 5~93' and 6050' and cement to retainer at ?092'. Make a scraper run, CBL and caliper,log run to retainer at ?092'. Make any required isolation squeeze's and clean out same. Perforate intervals 5818-5828' and 5?88-5796'. Run in 2 ?/8" completion assembly. Rig down and move rig to contractor's yard. The original procedure called for perforation and DST of 6172' - 6176 and frac job from 6172' - 6176'. We will not be performing that procedure ROW. This is the oniy change from the original procedure approved bY the Commission 4/18/86. WELL CLU ~3; ''? ' PRESENT Cmt ret @ 150' w/ cmt to surf . Cmt ret @ 5300' Cmt'ret @'5493' Cmt plug f/ 5555' to Cmt ret @ 6050' Cmt ret @ 7092' Cmt ret @ 7770' 7" Cmt ret @ 9280' i. 7" Cmt ret @ 9775' · 7" Cmt 'ret @ 10020' · ~ ~,-~ Jret @ 10391' 7" ..:~,~ ~,'.:.'..i~?:~:*,L~:.!;:'.~'~:.~.;,' :. . ~r:~-...~_':.~'.~..o.~l~ ,. "~ 20" Casing at 85' 13 5/8' Casing at 2895' Top 7' Liner at 7785' 9 5/8' Casing at 8130' PROPOSED Bottom 7' Line~:' at 11,125' Single Packer at +5145 5788'-5796' 5818'-5828" 6156'-6172' Att, achment No. 1 / WELL STATUS 1. 9 5/8II cmt ret- 150' w/ cmt to surface. 2. 9 5/8" cmt ret - 5300' 3.- 9 5/8" cmt ret - 5493' 4. Cmt plug f/ 5555' to 5955' 5. 9 5/8" cmt ret - 6050' 6. 9 5/8" cmt ret - 7092' 7. 9 5/8" cmt ret - 7770' 8. 7" cmt ret - 9280' 9. 7" cmt ret - 9775' lO. 7" cmt ret.- 10020' 11. 7" cmt ret - 10391' 10 11 3/8" C. 2695' _. - - Top of 7" @ 7783' '9 5/8" C. 8130' ETD - 10998' '=' 7" C. 11125' DATE CXD. CANNERY LOOP UNIT #3 AI'P'D. SCALE Spud' 5/26/81° Suspended· 9/13/81 UNION OIL COMPANY OF CALIFORNIA SHEETS f SHEL~ FORM 247 (N£W 5/66) 20" -'-'~,~-'; · ..]3 3/8' 61# I ._~9_5/8--j 47# I 7" .k 29# P1 a T ~ 2~-nT Buttress Buttress Bu_ttres~s +0 K-55 -80 - -80 ,.~I,: G ,.~_ --~::'""~ ........... L '~ 2695" 8130' --cmt'd w/ ih.lO sxs cmt. ..: Cmt'd w/-'-2005 sxs cmt". CLU' "~3 A'ttaChment #2 -- top ~ 7783'. Cmt'd w/ 1000 sxs cmt. PERFORATING RECORD ~:-9936-9938'... 1..0998] (FC) i, BS #1 J Sqz'd w/' lOO-sxs cmt thru ret~-9922' 7/22/81 9898-9900' 9922' (ret) i BS #2 ": Sqz'd W/ '250 sxs cmt thru ret @ 9850' J/23/81!...9408-9410' 9850' (ret):'BS #3 - "Sqz'd w/ 250 sxs cmt thru ret @ 9388' ..7/23/81 9372-9374' 9388'. (ret)_ BS #4 . Sqz'd w/ 550 sxs cmt thru ret @ 9270' 8/4/81_10530-10534' 10998' (FC) DST #l . ' " !0516-1052~' " " " " rod'. - Sqz!d thru ret @ 10391' w/ " 10504-10512' " " " "' ! 200 ~xs cFnt.. '" 8/6/8! !0504-!05!2' lnqqS' (FC) " " ,, 10128-10148' " -." DST #2 ) No pr'od. - Sqz'd thru Yet La iOOZU' w/ " 10128-10148" '' ) 200 sxs cmt. 8/9/81.. 9902-9915' 10020' (ret DST #3' I No prod. ~/l?/S'l q3S6.-9400' 9775' (ret) DST #4 . No prod Sqz'd thru ret @ 9280' w/ 300"'sxs ~/12/81 7246.7248' 9280' (ret) BS #9 Sqz'd W/ 250 sxs cmt thru ret @ 7222' ~/15/81. 7187-7189' 7222', (ret) BS #10 Sqz'd w/ 250 sxs cmt thru' ret @ 7109' " _~/16/8! ~6!7_~-6177' 7109' (ret) BS #11 Sqz'd w/ 250 sxs cmt thru ret @.6131' ~/16/Sl 60ql-6f193' 6131' (ret) BS #!2 L~SqzId w/ 250 sxs cmt thru ret @ 6040' _q/!7/8! E7q6-~7q2' 6040' (ret) BS #13 _V!~8! 5832~5~4' ,. 6nan' Cr~/ " " 15 ' s · _. ___..C_m_t2_cL~O0 sx cmt thru ret @ 5815' INITIAL PRODUCTION __D6T.._E ..... IUTERVAI, N_ET OIL ] CUT G.___~A___V_. C._P. ...... T;P. [ CHOK__E. ~j_.~cj_ GOR..~ .l ' I · ~, . - ,., . _ ,, TYPE: £AMFRON TRFIN WF1RKq CASING HEAD:_ 2'~I' 200f] psi SOW . CASING HANGER: 20" X '13 3/8" flow-thru' bol l-weevil type CASING ,SPOOL: 20" 2000 psi X 13 5/8" 5000 psi "wf'; ' TUBING HEAD:. , , 13 5/8" 5000 psi X' iO" 5000 ps~ "DCB" spool w/ 10" 5M blind flanqe TUBING ItANGER: TUBING iIEAD .TOP' MASTER VALVES: .. __ .,.. CH 1% !,~;T,!I :\ $ 'Fil I.:E 'l'()l~ CONN.: V;EIG}IT THREA~) GRAD}~ IIE".IAitKS PERFOitATII'IG RECORD 5422-5435' "~----~- --------~ °~k, Tq~iC~' ~ 9/11/81 PP, ODUCTIO_~T B/18/81 5779-5.781' _ 5815_' (ret) BS #14 ]_ Sqz_,'.d w/ 300 sxs cmt thru ret @ 5720' 3'/18/81 5601r5§03'- 5720' (ret} BS #15 Sqz'd w/.250 sxs cmt thru-ret @ 5585' 3/19/81 5565-5567' 5585' (ret). BS #16 Sqz'd w/ 200 sxs cmt thru ret @ 5484' B_/19/81 5412-5414' ....5484' (ret)__ BS #17 Sqz'd w/ 200 sxs cmt thru ret @ 5394' B2221ZBI 7194-7202' 7770" (ret) DST #5A ~ ~Zf, RJBd_. 7230-7238' ..."' " #5B[ No prod. - sqz'd w/ 150 sxs cmt thru 3/29/81 7228-7238' " " 5C ' ret @ 7092'. B./29/81 7192-7202' " --' " 5A ~ i 3/31/81 6156-6172' , 7092' (ret) DST #6 ~ No prod. - sqz'd w/ 250 sxs cmt'thru " 61 56-6172' " ' · "reperf~ ret @ 6050'. ~ ~q2134-5812' ' 605~-' (ret) DST #7A I) · 9/2/81' 5818-5828' " .. DST #7B I~. Had prod. - cmt'd w/ 130 sxs cmt f/ ~/'~/~ 57~-q7q6' " DST ~7£)' 59'55 to 57.62' -' -' i "' ~/7/~! 5584-5594' 5762' ) DST #8 . No prod. - cm~'d w/ 110 sxs cmt f/ ";"- _fi5B4-5594' " "reDerf~ 5761 to 5555'. p/n/hi ~na-_q~?n' .~H~I (cmt) nST #gA I~ No prod. -...~qz'd W/ 110 sxs cmt..t[{ru qlqlFtl 5508-5970' " "gA. reDor~J> _ret @ 5493' ~} ~ )_~ 8154, 58~_547. 0' _ . 5493_'_. ( r e t ) .... D_ST. #__9 B:' __[~_._ ~_1 5_0_ s x___5_s _c mt t__h r_u r e t @ 5~300-- 'W E__L.L H _EAD_ _A_$_bZ~.~JzI TYPE: CAMERON IRON WORKS CASING HEAD:___2_0 .... /000.._ps2_S0hL CASING HANGER:__2DJL_X...13_ 3./B" fl ow-thru bo'l 1 -weevi 1. type CASING SPOOL: 20" 2000 psi X 13 5/8" 5000 psi "wi". 13 5/8" 5000 psi' ~ 10".5000 ~si TUBING HEAD: , "DCB" sp6ol 'w/ 10" 5M blind flange. TUBING IIANGER: TUBING ilEAD TOP' MAS'FEI{ VALVES:__ ,APR 1 7 l. Stl CI.I R!,%T,!IA,q 'rill.:[.l TO}* CONN.: l CHOKE MANIFOLD HYDRAULIC VALVE' SEE DRAWING GATE FLEX HOSE IIF REQ. TO MUD PUMPS & CEMENT UNIT ~TE WELL NAME: RIG CONTRA C TOR: RIG: STACK PRESSURE RA TING: CHOKE LINE SIZE & MSP; .. ANGLED FILL UP LINE HYDRIL PIPE RAMS PIPE RAMS GATE GATE FROM MUD PUMPS & CEMENT UNIT BLIND RAMS CONTRACTOR FURNISHED OPERA TOR FURNISHED NOTES: 1. HYDRAULIC VALVES OPEN AUTOMATICALLY WHEN DIVERTER IS CLOSED. 2. FLEX HOSE IS TO BE USED AS NECESSARY. NOTE: ALL CHANGES MUST HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT DEPT. APPROVAL R ~"V. D AT E 13 5/8" BOPE STACK 5M OR 10M ALL WORKOVER OPERATIONS UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, ALASKA onAw. BHE CKO. CGN APP'D. SCALE N 0 NE DATE 6/26/65 SHEETS i S.EET HYDRAULIC FROM CHOKE LINE L .. WALl. OF___CHOK___E HO__,USE OUTSIDE OF CHOKE HOUSE 1 ~...j/3-, 5000psi TEE TO RESERVE PIT , / .TO GAS BUSTER . - ACTIVE PIT ·  TO RESERVE PIT NOTE: ALL TURNS WILL BE TARGETED 90 DEGREES RIG ¢54 BRINKERHOFF UNION OIL COMPANY OF CALIFORNIA -, NONE : ~.' ~. t0115185 · ' STATE OF ALASKA ALAS · OIL AND GAS CONSERVATION COM .31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 4. Location of well at surface 2790'S & 2440' E of NE Cor., Sec. 4, TSN, RllW, SH At top of productive interval 5. Datum elevation (DF or KB) GL 35' MSL 6. Unit or Property name Cannery Loop Unit 7. Well number CLU #3 8. Permit number feet At effective depth At total depth 11. Present well condition summary Total depth: measured feet true vertical ll, 125 feet 10,564 Effective depth: measured 150 feet true vertical 150 feet Plugs (measured) 81-58 9. APl number 50-- 10. -_A,i33-20340 YUV'Wildcat See Attachment #1 Junk (measured) Casing Length Size Structural Conductor 85 ' 20" Surface 2695.10 13 3/8" Intermediate 8130.17 9 5/8" Production Liner 3342.06 7" Perforation depth: measured true vertical Cemented Measured depth ~ueVerticaldepth Driven 85' 85' 1510 sx 2695.10 2626.28 2005 sx 8130.17 7687.71 1000 sx 11125.01 10564.65 See Attachment #2 RECEIVED Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) APR 1 7 1986 Alaska 011 & 6as Cons. Commission Anchora,qe 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 7/20/86 14. If proposal was verbally approved Name of approver Date approved 15. ' hereb~ certify t~a½_th~ foregoing is true and correct to the best of my knowledge Signed D' erts Title Environmental Enaineer -- Commission Use Only Conditions of approval Approved by Date 4/14/86 Notify commission, so representative may witness I Approval No. [] Plug integrity ,~ BOP Test [] Location clearance ...... ~,~ ~, ~ , by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate APPLICATION FOR SUNDRY APPROVAL CANNERY LOOP UNIT 12. Description Summary of Proposal 1. 2. . . . . . 10. 11. Wove rig onto existing CLU # 3 pad & rig up. Install and test BORE Cleanout drillable retainers 8 150', 5300' cement to retainer 8 ?092'. Wake 9 5/8" csg scraper run. , 5493' and 6050' and CBL and caliper log 9 5/8" csg to retainer ~ 7092'. Isolation squeeze as required and clean out same. Perforate and DST 6172' - 617~'. Perform frac job ~172' - ~17~'. Perforate 5818 - 5828' and 5788 - 5796'. Run 2 7/8" completion assembly. Rig down and move out rig. RECEIVED APR 1 ? 1986 Ala8~ Oil & Gas Cons. Commission Anchora!38 PROPOSED COMPLETION PRESENT PROPOSED ~ ~;'~;"~.~'~'.: '..i~. '°:~ ~'"'6'd.~:a :~'..o~. ~.~ ~o. Cmt ret @ 5300' Cmt ret @ '5493' Cmt plug f/ 5555' to 5 Cmt ret @ 6050' Ont rot @ 7092' . ~: ~',.Z.; :?..: =' .?~-.'6 .'; ~-. _.'.~ :.'.i Cn~ re~ @ 7770' 7" Cm~ ret @ 9775' ' . ~.._i, .~?.:~:/- ' ~.:: ... ~i.~L-.-.~''-~''''~ 20" Casing at 85' 13 5/8' Casing at 2895' Top 7' Liner at 7785' 9 5/8' Casing at 8130' Single Packer at _+5145'. :. .. -= = 5788'-5796' =.= 5818'-5828' ~ 6156'-6172' Attachment No. 1 ! WELL STATUS 1. 9 5/8" cmt ret- 150' w/ cmt to surface. 2. 9 5/8" cmt ret - 5300' ~.-, 9 5/8" cmt ret - 5493' 4. Cmt plug f/ 5555' to 5955' 1 --13 3/8" C. 2695' -_ 5. 9 5/8" cmt ret - 6050' 6. 9 5/8" cmt ret - 7092' 7. 9 5/8" cmt ret - 7770' 8. 7" cmt ret - 9280' 9. 7" cmt ret - 9775' lC. 7" cmt ret- 10020' 11. 7" cmt ret 10391' 5 Top of 7" @ 7783' lO 11 5/8" C. 8130' RECEIVED APR 1 7 1986 Alaska 011 & Gas Cons· Commissie.~ AIIC ETD - 10998' :':':":":'""'- 7" C. 11125' DATE CANNERY LOOP UNIT #3 AtPD. CKD. ~ ]I0/20/8I FORM 247 (NEW 5/66~ Spud' 5/26/81 Suspended· 9/13/81 UNION OIL COMPANY OF CALIFORNIA SHEE~S I SHEET SIZg'~ ',_._¥/EIGIIT I TPIREAD "i3 3/8' 61# [ Buttress __~9_5/8___'t 47# I _Buttres~s - 7" L 29# I Buttress . K-55 N-8___~O '] __- ~g~ .... Drive Pipe Dri CLU ~3 2695' ~mt'd'w/ Ib.'iU sxs cm~ A~achment ~2 813_._.0' ' 9mt'd W:~p~5 sxs cmt. .. i11~5~.[ top ~ 7783' ~' Cmt'd ~/ 1000 sxs cmt. PERFORATING RECORD . ' BS #1 qz'd w/ lO0-sxs cmt.thru ret--~ 99ZZ' - ~./21/8' 9936-9938' 10998~ (FC) , ]/22/81 9898-9900' 9922' (ret) j BS //2 Sqz'd W/ '250 sxs cmt thru ret @ 9850' 7/23/81 9408-9410' 9850' (ret) 'BS'~/3.... Sqz'd w/ 250 sxs cmt thru ret @ 9388' _7J23/81 9372-9374' 9388' (ret) _BS #4 . Sqz'd w/. 550 sxs cmt thru ret @ 9270' ' _8/4/81 10530-10534' 10998' (FC) DST #l ,, ln_~l~;_ln534, ,, ,, ,,..", . No prod. - Sqz'd. thru ret @ 10391' w/ -- _" 10504-10512' " " " " 200 sxs cmt. 8/6/8! !0504-!05!2' 10ggg' (FC) " " / -' ,' 10128-10148' " -." DST #2 ~ No prod. - Sqz'd thru Yet La IOOZO' w/ " 10128-10148i'' " ) 200 sxs cmt. 8/9/81. 9902-9915' lOOfOi' (ret DST #3 j No prOd. - Sqz'd thru ret @ 9775' w/ 200 sxs cm' _¥]?/ff1 q3R6.-g40g' .. 977.5' (re.t) .. DST #4 .' .No prod. 'Sqz'd thru ret @ 9280' w/ 300 "Sxs cm ~L12/81 7246.7248' 9280' (ret) BS #9 . Sqz'd W/ 250 sxs cmt thru' ret @ 7222' ~/15/81 7187-7189' 7222' .(ret) BS #10 Sqz'd w/.250 sxs cmt thru'ret @ 7109' ...... .¥16/8! . 6!75-6'!77' 7109' (ret) BS #11 Sqz'd.w/ 250 sxs cmt thru 'ret @.6131' ¥16/R1 60ql-6093' 6131' iret) BS #12 ~Sqz'd w/ 250 sxs cmt thru ret @ 6040' _V]7/8! 5796-.~79R' 604g' (ret) BS #t3[0 ' .V!7/el 083~-~n34" __anaa'_.ir~f% " ." L~__~~d_~-lO0 s~ss c~-~ {h~uu r-~t ~ §~1~' ___DLkT__E~ · I:[TERVAL NET OIL - TYPE:' £AMFRON TRON,WgRK$ _. GOR · CASING HEAD: 2'0" 2000 r)_~i SOW CASING HANGER: 20" X '13 3/8" flow-thru' bol 1 -weevi 1 type ' CASING SPOOL: 20" 2000 psi X ]3 5/8" 5000 psi "wf" ' · TUBING HEAD:, ]3 5/8" 5000. psi X' i0" 5000 psi "DCB" spool w/ ,]0" 5M b]i'nd'f]anqe, .i , TUBING ItANGER: TUBING iIEAD .TOP' MASTER VALVES: RECEIVED CI~Ii!STb..I:\S 'FREE '['OP CONN.:_ .. PRJ.-Z1985 Ala,slm (:iii & ~as Oons. Cmmmissie.~ Anchora§e SIZE _DATE 81.]8/81 S/18/81 8/19/81 8_/19/81 8/29/81 · 8_/29/81 8/31/81-- II 9~ 9/2/81' V/EIGiiT THREAD GRAD}i ILT. TO OCEAN FLOOR ~,'r. '1'O hlLL\V DI;C.~. , R.'I\.'llk lULL ' ~ R.T. TO P1XODUCTION DECK ,,'~i'IIOVED: DEPT}[ -. '. RE~4AiIKS E.T_.D.. . ~8_]_5: (ret) 57201 ... (ret) 5585' (ret) 5484'. (.ret). 7770" (ret) II. II 7092' (ret) ,, · . PERFOHATII,IG RECORD ~ BS #14 _ Sqg~d w/ 300, sxs cmt thru ret 0 5720' BS #15 BS #16 BS #17 " 5C ii 5A DST #6 II reperf DST #7A, DST #7B n.qT #7£ Sqz'd w/ 250 sxs cmt thru.ret @ 5585' 6050' (ret) II I.tI_~F~Cff2kI, 5779=5_781I ___ 5601-5603' ...5565-5567' ' 5412-5414' Sqz'd w/ 200 sxs cmt thru ret @ 5484' z'd w/ 200 sxs cmt thru ret @ 5394' No prod. '- sqz'd w/ 150 sxs cmt thru ret @ 7092'. ret @ 6050'. 7194-7202' 723O-7238' 7228-7238' 7192-7202' 6156-6172' 6156-6172' .~204-5812 I 5818'-5828' 5788-5796' 9/3/8! Q/7.,./~_. [, 5584-5594' "' L55B4-5594' q/a/al I 5508-55~'0 I 9/11/81 5422-5435' No prod. - sqz'd w/ 250 sxs cm't thru Had prod. - cmt'd w/ 130 sxs cmt f/ 5955 to 57.62~'. .. 5762' (cmt) t DST #8 l No prod. - cmt'd w/ 110 sxs cmt f/ ": I "reDerf ~ 576l to 5555'.__ I H~55' {cmt/I DST ~A ~ No prod,-- sqz'd w/ 110 sX.S. cmt..thru I "' '1 "gA"'reDeriS __ret'~ 5493' ' _ l~t_~l DS~ #9~' .~ ~w/ 150 sxs cmt thru ret @ 5300' ' .' DATE IIITERVAI. NET OIL TYPE: II CAMERON IRON WORKS CASING HEAD:~ ...... 20O0.._pM_SOW II .1~11 CASING HANGER: .... 29"_X.._13_3/_ flow-thru bo'l 1-weevil type CASING SPOOL: TUBING HEAD: . 20" 2000 psi X 13 5/8" 5000 psi "wf". · · 13' 5/8" 5000 psi'X 10"'5000 ~si "DCB" sp6ol w/ 10" 5M blind flange. TUBING t{ANGER:_ TUBING ilEAD .TOP: RECEIVED MASTER VALVES:___ . . C 1-I R !.%TM A S 'Fil I.,. [:: '1'O P CONN.: .... .ILI R ! 7 !986 Alaska 0il & fia$ Cons, Commission Anchorage ~ ANGLED FILL UP LINE . . HYDRIL .A~,,,* 4,0 HYDRAULIC '- ~ · VALVE' ~. ' ~ ~ ' ~"_~. ~.' ~'~ PIPE RAMS c.o~ - i1,~ilI . ~ ~ - ., , MANIFOLD · ~_,,.,~_, ' ~ -- GATE ,~] GATE ~ GATE GATE c--- ,-,vo~ ~' ~ & CEMENT UNIT 0__ IIF REQ' ' TO MUD PUMPS & CEMENT UNIT · C.~,..~ ~,..~BLINDRAMS ' ' " . ' . ~ CO-~',,~CTO, FU,~SH~O · OPERA TOR FURNISHED NOTES' 1. HYDRAULIC VALVES ·OPEN WELL NAME: AUTOMATICALLY WHEN RIG CONTRACTOR: DIVERTER IS CLOSED. RIG: STACK PRESSURE RATING: 2. FLEX HOSE IS TO BE USED . CHOKE LINE SIZE & MSP'.' AS NECESSARY. NOTE: ALL CHANGES MUST HAVE WRITTEN APPROVAL R E¢ EI V E D BY THE DISTRICT DRILLING SUPERINTENDENT ".' APR 1 7.1985 DEPT. APPROVAL Alaska 0ii & Gas Cons. Commission ~ch0rage REV. I DATE · , I 13 5/8" BOPE STACK 0,~w. ~,.~~0. c~, t · ' APP'D. { SCALE NONE t 5M OR 10M ~.~ i ALL. WORKOVER OPERATIONS. t UNION OIL COMPANY OF CALIFORNIA i ' ANCHORAGE, ALASKA · SHEETS i SHEET ._j j3', 5000psi TEE - TO RESERVE PIT · J . 3', 5000psi TEE (LOOKING UP~~) U _J ~, ~ ~RESSURE ( ~ a', sooo. ~ (SIDE VIEW) a L-w,,,O'c"o",.ous, ~ .. -- --, , / , To ~AS nUST~R ' /-- ' ACT, VE PIT · ~3', 5000'~ VALVE RECEIVED APR 1 7 1986 Alaska 0ii & Gas Cons, Commissio~ Anchera~e  TO RESERVE PIT NOTE: ALL TURNS WILL BE TARGETED 90 DEGREES RIG -~54 BRINKERHOFF UNION OIL COMPANY OF CALIFOI~NIA NONE 1OI15185 Union Oil and Gas Division: Western Region 'ifornia Union Oil Company P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union August 26, 1985 Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE INTENTION'S CLU #1 & #3 - KBU 13-8 Dear Hr. Chatterton: Attached for your approval are Sundry Notice of Intention's for CLU #1 & #3, Cannery Loop Unit, and KBU 13-8, Kenai Beluga Unit. Please return the approved Sundry's to the undersigned. LOC/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED AUG 2 9 Alaska Oil & Gas Cons. Commission Anchorage SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L L~L, OTHER [] 2. Name of Operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well 2790'S & 2440'E of NW Cor., Sec. 4, TSN, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) GL 35' MSL I 6 . Lease Designation and Serial No. Fee Lease Fredrickson 12. 7. Permit No. 81-58 8. APl Number 5o-133-20340 9. Unit or Lease Name Cannery Loop Unit 10. Well Number CLU #3 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation '[] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting an extension of site location cleanup for Cannery Loop Unit #3 for one year per regulation 20 AAC 25.170.(b). This site may be used for additional development work at a later time. The site has been cleaned up with the exception that the pit still exists. fence has been erected around the area. The well has been left with 9 5/8" casing to surface with a 13 5/8" 5000# x 10" 5000# DCB spool and a compaion 10" 5000# blind flange with a relief valve on top. AUG 2 9 1985 Alaska Oil & 6as Cons. (;ommlllaion Anchorage Signed L~wrence ~, %~t~ Title ENVIRONMENTAL SPECIALIST The space below for Commission use Date08/23/85 Conditions of Approval, if any: Approved by Approved Co, ay Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ..... ( .... STATE OF ALASKA r/' ALAS~ (~]L AND GAS CONSERVATION~,.)MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator UNION 0IL CONPANY OF CALIFORNIA 3. Address 4. Location of Well P. 0. BOX ~247~ AN£HORAGE: ALASKA 99502 2790'S & 2440'E of NW Cot, Sec 4,TSN,RllW,SM 5. Elevation in feet (indicate KB, DF, etc.) GL 35'MSL 7. Permit No. 81-58 8. APl Number 5o-~33-20340 9. Unit or Lease Name I 6 . Lease Designation and Serial No. Fee Lease Fredrickson 12. CANNERY LOOP UNIT 10, Well Number CANNERY LOOP UNIT .~.~3 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting an extension of site location cleanup for Cannery Loop Unit It3 for one year per regulation 20 ACC 25.170.(b). This site may be used for additional exploratory work at a later time. The site has been cleaned up with the exception that the pit still exists. A fence has .been erected around the area. The well has been left with 9 5/8" casing to surface with a 13 5/8" 5000ti x 10" 5000¢f DCB spool and a companion 10" 5000¢f blind flange with a relief valve on top. RECEIVED AUG 2 4 1'984 Alaska 0ii & Gas Cons. Commission _t Anchorage 14. I hereb hat the~_or~ftr~,~~_rect to tl~ll~est of my knowledge. ~ S!gne~__~ ' SIM R. CALLENDER Title DISTRICT DRILLING SUPT. Date 08/17/84 elow for Commission use itions of Approval, if any: Approved Copy r, ~ _ .~'e-turned E~¥ [~'~'~,IE C. SMITg By Order of Approved by, OOMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~o~,? MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION OATE: August 21, 1984 F, LE NO: A. 5e. 4 -' TELEPHONE NO: SUBJECT: Inspection of -'- Suspended Well Locations, Cannery Loop Unit Well No. 1, Sec. 7, T5N,RllW,SM, Permit No. 78-95 and Cannery Loop Unit Well No. 3, Sec. 4, T5N,RllW,SM, Permit No. 81-58. TO: C.V.~~t~ton Chair~J'~ THRU.. Lonnie C. Smith//~/0 Commissioner Petroleum Engineer Thursda¥,.'August 16~ 19841 I departed Anchorage via South Central Airlines at 12~00 noon and arrived at Kenai airport at 12:30 p~.;.- . where I was met by Mr. Larry Cutting, Union Oil Company of ~ California representative. We first drove to the Cannery Loop Unit Well No. 3 location. This location was surrounded by a chain link fence and locked gates. The pad was clean and free of debris, the reserve pit was open, and has some brown water (no oil sheen) at one end, the well sign was attached to the gate (all data on sign was correct) and all outlets on wellhead were plugged. We then drove to the Cannery Loop Unit Well No. 1 location. This location was also surrounded by chain link fence and locked gates. The pad was clean and.free of debris, the reserve pit was open and dry, the well sign was attached to the fence, the rat hole was open and all outlets on wellhead were plugged. The location on the Cannery Loop Unit Well No. 1 well sign read "376'N, 188'W of the SE corner...". This was corrected to read · "376'W, 188'N of the SE corner.." · · Photographs' to verify the condition of both locations were taken and are attached to this report. I filled out the AOGCC reports which are attached. In summary, the locations for Cannery Loop Unit Wells Nos. 1 and 3 are satisfactory for extension of suspended status. Attachments · 02-00'~A(Rev. 10179) Suspended Well and Location Report 20 LAC 25, ARTICLE 2 FILE I NFOt~ATION: Operator Address Surface n6ca~ion 0f aT~D Ft. F~ L, Sec. ~, T ' - -- Well No. ' ..... ~ Field & Pool' Condition of Pad_ Condition of Pits ~)L)D Well head - Ail outlets plugged ~ No Well sign - Attached to well head 'Yes Attached to well guard Yes Attached 'to ~-J/7-~A/_~' ~~'~[' Information correct  No Cellar - Opened ~ No Fil led Ye s ~ Covered Yes WaterWell - Plugged off ~Ca~p~ Open Rat Hole ~n~'7~ ~'~/~"E'~'~YeS Fi 1 led 'Ye s Covered Yes. Explanation Photographs taken to verify above .condition~ No Explanaton Work to be done to be acceptable /.tg~'TT~>~ h~":"~'~'~[f~,:[ " This well and 'location is ~ (unacceptable) to be classified as suspended for the period of 19_ thru 15__.. · Inspected by: ~~~/~/~ //~J~'~.~_-.~ Da te: ~//,~/~3~,/ Revised 8/24/82 MEMORANDUM State of Alaska ALASKA OIL AND -~GAS CONSERVATION COMMISSION TO: C. fV ~~t~erton Ch~ THRU: Lonnie C. Smith Commissioner DATE: FILE NO: TELEPHONE NO: July 13, 1983 10SA:G1 FROM: ~arold R. ~awkins Petrole ~um Inspector SU BJ ECT: Inspect Location for Extension of Clean-up, Cannery Loop No. 3 Union Oil Company Sec. 4, T5N,RllW,SM, Permit No. 81-58. .Tuesday,._~ July_12,. !983: I left Anchorage at 7':45 am by South central Air 'to Kenai arriving at 8:15 am. The clean-up inspection was performed, the location was clean and free of debris. Surface location data is incorrect on well sign. i took pictures to verify Condition of location and well sign which is attached. I filled out an A.O.G.C.C. report which is attached. In s~mary, the location of Cannery Loop No. 3 is suitable for extension of clean-up, except for the surface location data the wel 1 s Attachments August 25~ 1983: Union Oil has changed the well sign location ~ata With'the-right data on Cannery Loop No. 3. Larry Co:tings, supervisor on the extension for suspension for Union Oil, brought pictures in for verification. Location now ok for extension of suspension. See pictures attached to this report. ~?.~:::..~.~ 02-00IA(Rev. 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 Operator ~/~/~ ~/_~ ~O~?_~3/_~.F ~/~.t/-O~,~h;-'~' Date Suspended Address /~ ~ .~X~7 ~j~ ~/~3 ~lSZ ' _ _. Surface Location of We%l- ~'-' Pe~mi-t- No.-. ~/-~J~-~- ~7YO'~Ft. F2~d/~5, ~t. F n aPI No. 50 ~..73-~~ Sec. ~, T ~ ~, R~/ ~, ~M. Unit or Lease NameA~x?~F. ..... Wel 1 No.- _~ ~/ Field & Pool ~{X~_~F Condition of Pad Condition of Pits Well head - Ail outlets plugged Well sign - Attached to well head' Yes Attached to well guard Yes Attached to Information correct Yes Cellar - Opened ~ No Fi 1 led No Cove red Ye s No WaterWell - Plugged off capped Ope n Rat Hole Open Fil led Covered Explanation YeS o Ye s Ye s No Photographs taken to verify above conditions ~_~j No Exp la na ton ~_../':/£'?"~):?z'~: Work to be done to be acceptable .,A :~,,,,fTll,Z~ ,,'3~. J/£,,~ /~'",~T ~P/?/':/~t%E,?[~i~'?-~z?'~9 This well and location is (~cceptable)~(ufRccep~able) suspended for the period of-- ' ~ 19 · thru Inspected by: Date: ~////~/~ to be classified as 19 . Revised 8/24/82 / STATE OF ALASKA ALASK L AND GAS CONSERVATION C ,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. UNION OIL CONPANY OF CALIFORNIA 81-58 3. Address 8. APl Number RO BOX 6247 ANCHORAGE AK 99502 5o-133-20340 4. Location of Well 2790'S & 2440'E of NW corner, Section 4, TSN, RllW, SN. 5. Elevation in feet (indicate KB, DF, etc.) GL 35' MSL 12. I 6 . Lease Designation and Serial No. Fee Lease Fredrickson 9. Unit or Lease Name CANNERY LOOP UNIT 10. Well Number CANNERY LOOP UNIT #3 11. Field and Pool WILDCAT Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, inCluding estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting an extension of site location cleanup for Cannery Loop Unit #3 for one year per regulation 20 ACC 25.170.(b). This site may be used for additional exploratory work at a later time. The site has been cleaned up with the exception that the pit still exists. A fence has been erected around the area. The well has been left with 9 5/8" casing to surface with a 13 5/8" 5000# x lO" 5000# DCB spool and a companion lC" 5000# blind flange with a relief valve on top, Approved Copy .. Returt~ed - ..... &nch0rage 14. I he tifg that th~~s true and correct to the best of mg ,,,n~~ ~/j/~~ ~~itle b's~'O~ D~'g Supe~,n~enden~ Date Oo m,s,,on ~nditions of Approval, if any: .... - ~ xepxeseatatxve ~pected ~xs sxte o~ 07/~3/83 ~d c~e~ sat~s~acto~ ~c~t tbexe ~s ~o we~ si~. S~se~eat~ o~ 08/25/83 pboto~apb~ was submitted that this ~11 sign was properly installed. A subsequent inspection will be necessary by August 1984. By Order of /~) ~ (~5:~ _~ Approved by ,~Uil' tlt~ll[~' COMMISSIONER the Commission Date ~ - Form 10-403 Submit "Intentions" in Triplicate Rev. 7-1-80 ~¥ LONNIEC. SMITI! and "Subsequent Reports" in Duplicate mi February 4, 1983 Mr. Robert T.' Anderson District Land Manager Union Oil Company of California P. O. Box 7247 Anchorage, Alaska 99502 Dear Mr. Anderson~ The Alaska Oil and Gas Conservation Commission has recently checked the records of wells completed since January 1, 1979. This review has revealed that the digitized data for certain logm run in a well is not on file with the Commission. The Oil and Gas Regulations require the operator to file, within 30 days after completion, suspension, or abandonment of a drilling well, the digitized data, if available, for copying, for all logs run in the well except velocity surveys, experimental logs and dip- meter surveys. We would request that you check your records to' see if the data has been submitted to the Commission and, if not, that you comply with the regulation with regard to. the following wells~ Trading Bay Unit No. D-34A Trading Bay Unit No. D-15 RD Trading Bay Unit No. D-3 RD Trading Bay Unit No. D-25 RD Trading Bay Unit No. K-2I RD Trading Bay Unit No. K-24 Tungak Creek No. 1 Trading Bay St. Mo. A-17 RD Cannery Loop Unit No. 1 Cannery Loop Unit Mo. 2 Cannery Loop Unit No. 3 Kenat Tyonek Unit No. 43-6X Thank you for your cooperation in this matter. Yours very truly, / Harry W. Kugler - Commis s toner BY ORDER OF T~'LE CO~'~MI SS I0~ be iL STATE OF ALASKA G(:~ ALASKA AND GAS CONSERVATION C ,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator UNION 0IL CONPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well 2790'S & 24/~0'E of the NW corner, Sec. 4, TSN, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) KB +63 ' MSL 12. 7. Permit No. 81-58 8. APl Number 50- 133-20340 9. Unit or Lease Name CANNERY LOOP UNIT 10. Well Number CANNERY LOOP UNIT #3 11, Field and Pool 6. Lease Designation and Serial No. Fee lease Fredrickson WILDCAT Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing . [] ~ Perforation's [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting an extension of site location cleanup for Cannery Loop #3 beyond one year per regulation 20 ACC 25.170. (b), for an additional five (5) years. This site may be used for additional exploratory work at a later time. The site has been cleaned up with the exception that the pit still exists. A fence has been ereoted around the area. The Well has been left with 9 5/8" casing to surface with a 13 5/8" 5000# x 10" 5000# DCB spool and a companion 10" 5000# blind flange with a relief valve on top. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Approved Copy~ ~ Returned Fi'~/(a Oil & Gas 00ns Signed ~,~. ~'~-. 0~0J~O.~l~)0~ ~//~,-t~ Title D[~T DRL~ SUPT Date The space b~w for C~mmissio~use--- - y~ Conditions of Approval, if any: ~e site ~]e~ ~ is app~oved ~t ~eause the pit is open is e~ipp~ ~th well head fittings, the site location is approv~ for ~ 'additional · one ~ar ~ri~ only.~e~te ~st ~ reins~cted each ~ar for consideration for. ~:"approval O~ additi~~t,e~ion. Approved by ' ~XX~ COMMISSIONER the Commission Dat ~' Form 10-403 Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate DEI~%RTMENT ()¥ NATI~RAL RESOI~RCES MINERALS AND ENERGY MANAGEMENT May 6, 1982 Mr. Robert T. Anderson Union OilCompany P.O. Box 6247 Anchorage, AK 99502 JAYS. I-IAMMOND GOVERNOR 't'~-~"~ --::- ~- -_ 555 CORDOVA STREET f.. .... Reference: Cannery..._Looo Unit #1' Well Dear Mr. Anderson: '~"~ from you in response to my decision to On April 30, 1982, I received a ~. request that the Alaska Oil and Gas Conservation Commission release confidential well data pertaining to the Cannery Loop #1 Well on May 31, 1982. Specifically, you indicated in your letter that there was additional unleased acreage consisting of submerged lands in the Kenai River within the Cannery Loop Unit which have not been offered for competitive leasing. You requested that the confidentiality of these data be extended, pending the disposition of the submerged areage. A review of our records indicates that portions of Sections 4, 9, 10, and 16 of Township 5 North, Range 11 ~est, Seward Meridian, contain unleased lands. I have asked my.staffto begin the necessary preparations to offer this acreage in an exempt competitive sale. The confidentiality of the data from the Cannery Loop #1 Well will be maintained until 30 days after these lanOs have been leased. In addition to discussing the Cannery Loop #1 Well, you requested extended confidentiality for the Cannery Loop Unit #3 Well. Our records indicate that the data from that well are scheduled to be released on October 13, 1983. Since these data will remain confidential until that time under normal procedures, it is premature at this time to request extended confidentiality for that well. In the event that an exempt sale including unleased acreage A~ska Oii& Gas (;ohs. Oomrnbsion Anc!tm'ag~ Mr. Robert T. Anderson May 6, 1982 Page 2 within the Cannery Loop Unit has not been 'held prior to September 1, 1983, it would be appropriate for you to request extended confidentiality for these data at that time. By copy of this letter, I am informing the Alaska Oil and Gas Conservation Commission of my decision regarding your requests. Sincerely, Dir~btor cc: John W. Katz, Commissioner, DNR C. V. Chatterton, Chairman, AOGCC Robert T. Anderson O~slric! Land Manager union Union Oil and Gf, .... ~ivison: Western Regio~lfj Union Oil Comp~,y of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 ~ J STAT TEC-- April 30, 1982 ~. ' ~ · ~ ~,,, , Ns. Kay B~own, D~ecto~ DLv~sJon of HSne~a}s A Energy Hanag~ent Department of Natu~a~ Resources Pouch 7-005 ~ncho~age, ~}aska ~25}0 CANNERY LOOP UNIT State of Alaska ConfidentialitY of wei~ Cannery Loop Unit #1 ~nd # ~')' Wells ~ Dear Ns. Brown: we are in receipt of your letter of April 26, 1982, wherein you expressed your intention to request the Oil and Gas Conservation Commission make public data 'from the Cannery Loop #1 well on Nay 31, 1982. Rlease be advised thatby letter dated March 26, 1982, a copy of which is attached, Union Oil Company, as Operator of the Cannery Loop Unit, requests~the extension of confidentiality on Cannery Loop Unit #1 and #~ wells. As set forth in said letter, the reason for the request is that unleased state lands lying within the Cannery Loop Unit were not offered' in either State Oil and Gas Lease Sale No. 32 or 33. We therefore requested that the extended confidentiality be for a period until after a sale is held which includes those unleased State lands in the Cannery Loop Unit. Thank you for your attention to this matter. Very truly yours, erson cc: 3ohn W. Katz, Commissioner, DNR C. V. chatterton, Chairman, AOGCC .- I ECEIVEo MAy o ]982 Alaska Oil & Gas Cons. ' . Anchorage u,,~u,, uil and L~as UNison: Western Region Union Oil Companf ~ California P.O. Box 6247, Ar~ .rage, Alaska 99502 Telephone: (907) 2'/6-7600 Robert T. Anderson District Land Manager March 26, 1982 Commissioner John Katz · Dept. of Natural Resources Pouch M Juneau, AK 99811 CANNERY LOOP UNIT State of Alaska Confidentiality of Well Data Cannery Loop Unit #1 Well. Dear Commissioner Katz: Union Oil Company of.California, as'operator,for the Cannery Loop unit and on behalf of itself, and the affected working interest owners, hereby requests that all data submitted to the State of Alaska regarding those certain wells designated as Cannery Loop Unit #1 and #3 be held confidential for an indefinite peroid of time. The request is made pursuant, to Alaska Statute 31.05.035(c). The reasoning for maintaining the well data Confidential is that the reports and information filed pursuant 'to AS 31.05.35(a) contain significant infor- mation relating to the valuatiom of unleased land in the same.vicinity as the Cannery Loop Unit #1 and #3 wells. I reference that certain letter' of May 4, 1981, from Commissioner Robert E. LeResche, wherein he grants a~ extension of the confidentiality period for a reasonable time after awarding leases for Oil and Gas Lease Sales 32 and 33. In as much as these two lease sales have been held.and failure' to put up the unleased land within the umit boundryof the .Cannery Loop Unit for competitive bid, an extension of the confidentiality for an indefinite period is warrented until after such time that those lahds are included in future oil and gas lease sales. Very truly yours, KAT:bde · cc: Kay Brown, Director Division of Minerals & Energy Management Robert T.. Anderson .RECEIVED MAY 0 1982 Alaska Oil & Gas Cons. Commission' Anchorage R. C. Warthen District Development Geologist Alaska District Union Oil and Gas ;ion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union April 27, 1982 Mr. William Van Alen State Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Bill: Enclosed is the data you requested as per your letter of 4-22-82. As you check the document of transmittal, you will note several items are missing. They are as follows: TBU D-9 RD Library tape;, this tape is currently being redone and reproduced by Schlumberger. TBU K-3 RD Well History; Union Oil as TBU Operator has no receipt of receiving this history from ARCo- suboperator. We are currently checking with ARCo on this matter. Library tape; as a confidential well, the logs have never 'been composited by Schlumberger and therefore a library tape is not available. When available, the tape will be delivered to the Oil and Gas Commission. KU 34-32 Test reports; these test reports have not been delivered to Union Oil Co. from Haliburton at this time. R. C. Warthen RCW:nd Hr. Robert C. Warthen Union 0il Company of California P. O. Box 6247 .: ,Anchorage, Alaska 99502 Hissing Information - Completed Wells Dear Bob: April 22, 1982 Well C0mp le~t. ion Date Missing Material Granite Pt. ~33-14ED 3/6/81 -D~L/SP & CBL/VDL Elec. Logs. Trading Bay Unit tD-9RD . :3/2/82 -Digitized E. Log Tape Trading Bay Unit tD-16RD Trading Bay Unit ID-17RD 5/8/81 6/22/8.1. -Directional Survey -Elec, Logs -Directional Survey Trading Bay Unit #K-3RD S/22181 -Well History Trading Bay St. #A-gED s/ /s1 -Directional Survey -Digitized E. Log Tape Trading Bay St. ~A-17RD '~"~nneryLoop Unit Kenai Unit #34-32 7/3/8,, 9/13/81 1118/82 -Digitized E. Log Tape -Digitized E. Log Tape -Digitized E. Log Tape -Certified Survey Plat -Directional Survey -DST or Prod. Test Reports Trail Ridge Unit #1 12/13/80 -Certified Survey Plat Please submit the above material at your earliest convenience since you are now in violation of Title 20, Chapter 25 of the Alaska Admin- istrative Code. Very t~.uly ~jours, William Van Alen Petroleum Geologist WVA:vdl We wish to bring to your attention that the below-indicated material on the following Union Oil Company wells has not yet been received by the Alaska Oil and Gas Conservation Commission: Document Transmittal Union Oil Company of Califor union DATE SUBMITTED ACCOUNTING MONTH HAND DELIVERY 3-15-82 TO i FROM William van Allen R.C. Warthen ^T State 0il and Gas AT PO box 6247 Conservation Comm. Anchorage, Alaska Anchorage, A1 aska ~E'EP,ONE TRANSMITTING THE FOLLOWING: ! Core chi ps o1: Cannery Loop Lnit #3, Core #1 from 10,545' to ~0,~73' 29 samp] es " PLEASE SiGN AND .RETURN ONE ~.0PY RECEIVED: DATE: FORM 1-2M02 (REV. 1 1-'72) PRINTED IN U.S.A. ALASKA OIL AND GAS CONSERVATION COMMISSION 'THRU:Commis~onerL°nnie'[C'' Smith Doug Am6s ~troleum Ins~ctor February 23, 1982 Conduct Clean-up Inspection on Union Oil Company's Suspended C o Dnit Sec. 4,--TSN, RilW, S.M. Friday,...._October_ 2, 198_1 - Mr. Ed Sipple and I traveled this date from Anchorage to Kenai to conduct clean-up inspection on Union Oil Company's suspended Cannery Loop #3 well. As the attached photographs indicate the location is clean and graded. However, as shown by photos 5-7, there is no well sign, the cellar is open, the rat hole is above" the final grade and the mud pit contains some oil or oily material floating on the water contained within it. ,! Therefore, I recommend that the Commission not grant clean-up approval until the above mentioned items have been corrected and a follow up inspection conducted. In summary, we conducted the clean-up inspection on union Oil 'company's suspended Cannery Loop Unit No. 3 well. Due to no well sign, the open cellar, exposed rat hole and oily debris in the mud pit, I recommend that the Commission not grant clean-up approval to this location until the afore mentioned discrepancies have been corrected and verified by a petroleum inspector. ALASKA OIL AND GAS CONSERVATION COMMISSION THRU: Chat 'chatterton Chaiman Lonnie C. Smith Commissioner Doug Amos~ Petroleum Inspector February 18, 1982 Conduct Clean-up Inspection on Union Oil Company's Suspended Cannery Loop Unit No. 3 Well Sec. 4, T5N, RllW, S.M. Friday, October 2, 1981 - Mr. Ed Sipple and I traveled this date ~0m An~-horage- t~ Kenway'' to conduct clean-up inspection on Union Oil Company's suspended Cannery Loop $3 well. As the attached photographs indicate the location is clean and graded. However, as shown by photos 5-7, there is no well sign, the cellar is open, the rat hole is above the final grade and the mud pit contains some oil or oily material floating on the water contained within it. Therefore, I..~.'~commend that the Commission not grant sUSan ~'/ '~ until the~ above mentioned items have been corrected and a follow up inspection conducted. In summary, we conducted the clean-up inspection on Union Oil Company's suspended Cannery Loop Unit No. 3 well. Due to no well sign, the open cellar, exposed rat hole and oily debris in the ... mud pit, I recommend that the Commission not"-grant'~susp~s.~on ' ~~S to this location until the afore mentioned discrepancies have been corrected and verified by a petroleum inspector. \ 20 AbC 25, 'iUi'[CI.I~ 2 Surface Location of Well l',:rmit 20 AAC 25 120: WF.I~L AI;Ai';I)O .... ,:v-,. - .... ',~ .... H,\ R J-, l']l-I: Dia. Steel PostI (4"Nih.) }te ight Above Final Grade l~evo, 1 (4' Min.) Top of Harker Pipe Closed witi~: Cement PLug Set: On Well tlead , On Cutoff Casing Distance Below Final Grade Level Side Outlets: All Valves and Nipples Removed All Openings Closed , With Blinds Length (lO' Hin.) Screw (:at, , In Concrete Pl~g Ft. in. Welds , Witi~ Cement , Other INFOIiHATION BE,\DWEI, I)EI) I) (LiSt ~q~ere Different from [:ile Information) Operator ~pl'l~w~ ~)i [ [~o, Unit c>r Lease Na,ne Well Number , 'Surface Location of Well: Ft. F L, Ft., t" L, Sec , T , R 20 AAC 25.170: LOCATION CLt'~AN-UI' PITS: Filled In , Liners Removed or Bur:Led , Debris Removed SURFACE OF PAl) AND/OR LOC:AT Rough , Smooth ~...-/', Contoured Other Flat L ,, Compacted CLEAN UP OF PAD AND/OR I,OCA'I'ION: ~ ~ ) 1~ Clean Pipe Scrap Iron SeraI od Paper , Other ~ ~ ~ ~. ~'~..~ , bIuci L~, Cement SURR(')LJNI)ING ARE:\: Wooded Brush Sand , Other , Dirt , Gravel , CONDITION SURRt)UND[NG ARI']A' ._~, "T r r om Clean 351x f Site Other , Trc'es and/or Brush from Clearing Site ACCESS Dirt , Gravel~, Ice , OLiver CONI) \"\'ION AC(.~ ROAD AND SURROUNi)IiNC: Clean ~ Rough __, ~n'looth , 'l'l-,~sll from Ol)Ot';tt'LOt~__' Trees and/or Brush from Clearing Road , Spoil fro.n Clearing Road Other kt Final Inspection I---3 February 19, 1982 ..Un~on":Oil Company of. California P.O. Bco~ 6247 Anchorage, Alaska 99502 Clean-up'Inspecti°n of the Following Suspended Locations: Cannery Loop Unit I~o. 1, Sec..7, TSN, Rl1~, .~ Cannery Loop Unit No. 3, Sec. 4, TSN, RllW, SM Gentle, n: · These. sites were ins~ected by our representative on October 1981. The following deficiencies~.~in.' the .clean-up were noted~ .. Cannery _ LO-OD:_ U~!t. No. 1 ' .i* A two inch (2,,} open flange on the 9 5/8" casing valve needs to be fitt~ with a blind flange '~ 2." A 55 gallon dr~ and a-~V pipe need to be removed fr~ the. site 3. Some oil~ residue in the pit area needs to be cleaned i. A'-W~ll sign 2. The cellar is open and needs to be c'los~d over 3. The rat hole shoul~ ~ ~ut off to the final grade and capped 4. Oily ~aterial on water in the c~eaned up. It will be necessary to submit a form 10-4'03, Sundry Notices and Re~orts on Wells, to request a one year extension of time for s~ch items as open pits which fall under the requirements of 20'AAC 25.170 LOCATION CLEAN-UP. Please 'notify us when 'these corrections have been made. A .s~se~ent inspection of these wells will b~ necessary. /~ STATE OF ALASKA [MISSION ALASKA C~r AND GAS CONSERVATION CO SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. UNION OIL CONPANY OF CALIFORNIA 81-58 3. Address P0 BOX 6247 ANCHORAGE AK 99502 4. Location of Well 2790'S & 2440'E of the NW corner, Sec. 4, TSN, RllW, SH. 5. Elevation in feet (indicate KB, DF, etc.) __ KR +~ MS1 12. I 6. Lease Designation and Serial No. Fee !ease Fredrickson 8. APl Number 50- 1~3-203/z0. 9. Unit or Lease Name CANNERY LOOP UNIT 10. Well Number CANNERY LOOP UNIT 11. Field and Pool WILDCAT Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting an extension of site location cleanup for Cannery Loop Unit ¢13 beyond one year per regulation 20 ACC 25.170 (b), for an additional five (5) years. The site may be used for additional exploratory work at a later time. The site has been cleaned up with the exception that the pit still exists. The well has been left with 9 5/8" casing to surface w/ a 13 5/8" 5000# x 10" 5000# DCB spool and a companion 10% 5000# blind flange with a relief valve on top. An onsite inspection was conducted by Doug Amos, OGCC and Union Oil on Oct. 23, 1981. RECEIVED DEC2 3 198! Alaska 0ii & Gas Cons. C0mmissi0. Anchorage 14.1 heleby c~rtify that th~for~eej~ing is true and correct to the best of my knowledge. ~mnec~ ~-~-~'/Si ne,, ~...y__..~t~.~.~k J. ,/~,//~U//~,~/~ TitleDIST DRLG SUPT Date12/18/81 T~spa~-f~r Commission u~ ' - .... on ~ons of Approval ~f any ~..~onsofAppr, ',' : Per Can~ission policy, extension of site location clean-up is approved for an additional C~TE YEAR period and subject^psp'~r}&omu~,~ybe reinspected each year before extens ion i s considered. Returned ~['~t~i~¢L S~,~Li~ ...... By OrderoT ....................... SSlOn Approved by ,~m ,~.,~i;.' ~ 6-;,~;~T~ COMM,ee,~,c~ +~ r-~; - Date Form 10-403 ~t~ [~i'~[; ~. e~,~ ~,, Submit "Intentions" in Triplicate Rev. 7-1~0 and "Subsequent Reports" in Duplicate Document Transmittal Union Oil Company of Califc unlen DATE SUBMITTED ACCOUNTING MONTH 11 - 16-81 ,,,,, TO FROM Mr. William Van Allen R.C. Warthen State (li l & Gas Cons. Comm. Pouch 6247 AT3001 Porcupine Drive AT Anchorage, AK 99502 Anchorage, Alaska 99504 TELEPHONE NO. TRANSMITTING THE FOLLOWING: 1 cpy DST report #7 --- " PLEASE SiGN AND RETURN ONE (:OPY UA!E' NOV 1 ? Ic :": ~s~ 0~I & G~S Cons. Corm ~ission ..... ,. - FORM 1-2M02 (REV. 1 1-72) PRINTEO IN U.S.A. union DA'rE SUP-MITTED ACCOUNTING MONTH HAND DELIVERY 11-3-81 T O .... FR(~M Harry Kug]er R, C. Warthen Alaska Oil and Gas Pouch 6247 ^? Conservation Commission AT Anchorage, Alaska 99502 3001 Porcupine Anc~roage, Alaska TELEPHONE NO. TRANSMITTING THE FOLLOWING: r ....... ~^~ II"~t #3' ~ copy, Di~^~'~' ~u, ~ , ,=~l~,,~lc ....... PLEASE SIGN. AND RE"URN ONE ;OPY ' .,..~ / RECEIVED: DATE' AJ,,'] V ] .41aska Oil & Gas ....... ,,, .... , ...... ...... .... i i FORM 1-2M02 (REV. 11-72 PRINTED Itt U.S.A. Union Oil and Gas [" on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union R. C. Warthen District Development Geologist Alaska District October 20, 1981 Mr. Harry Kugler Alaska Oil and Ga~': Conservation Commission 3001 P°'~cupine Drive Anchorage, Alaska 99504 Dear Mr. Kugler' Enclosed helrewith are samples, logs, and DST :Test Reports, ~?S required upon the completion of Union Oil :.Cannery Loop Unit #3...Since this is a confidential well, Union Oil Company, as operator, died not permit the logging contractor (Schlumberger) tQ composite and "finalize:,' the wireline logs. The enclosed bluelines and sePias therefore represents the "final" logs. Library tapes of the wi. reline logs will be forwarded to the Oil and Gas .Conservation Commission when available. : R. C. Warthen RCW:nm ~ STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CCiM'MIssION WELL COMPLETION OR RE;COMPLETION REPORT AND -1. Status of Well Classification of Service Well : · . OIL [] GAS ~ SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Union 0il Company of California 81-58 3. Address 8. APl Number P. 0. Box 6247, Anchorage, Ak 99502 50-133-20340 ._ 4. Location of well at surface 9. Unit or Lease Name 2790' S and 2440' E of the NW cor Sec 4, T5N, RllW Cannery Loop Unit .. At Top Producing Interval 10. Well Number 2138' S and 1035' E of the NW Cor Sec 4, ~T5N, RllW Cannery Loop Unit #3 · At Total Depth 11. Field and Pool l~Cl' ~ ~nrl ~R&' W nf tho NF £nr _~oc .~. TSN, RllW .5. El'e;a'~i~n in-fee~'(i~di~'ale'KB,-bF7 ;tc.)- ..... 1-61 Lease Designation and Serial No. 63'KB ] Fee Lease - Fredrickson Wildcat 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions .~-?R-21 7-12-81 9-13-81 N/A feet VSL N/A 17. TotaI,DepthT (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21 . Thickness of Permafrost (~0552:_ VD)ll125MD Surface . Y Es)~ NO[] N/A feet MD N/A 22. Type Electric or Other Logs Run DIL, BHC, FDC, CNL, HUT, CST 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# Surface· 85' 20 , 13 3/8" 61# K-55 Surface 2695' 17 1/2" 1510 sxs c/ "G" 9 5/8" 47# N-80 Surface 8130.' 1·2· 1/4, 2005 sxs c/ "G" 7,' 29# N-80 8130' 11125' 8 1./2" 1000 sxs c/ "G" - I , 24. Perforations open to Production (MD+TVD of Top and Bottom and ... 25. TUBING RECORD interval, size and number) SIZE .. DEPTH SET (MD) PACKER SET (MD), , None DST #7 .'~.....' .,.. .... 5818' - 5828' MD (5497' -5506' -'TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5788.' - 5796' MD (5469'-5476' TVD).'-.,. ~ ..:... DEPTH INTERVAL (IVtD) AMOUNT & KINDOF MATERIAL UsED ' _~oo_ at'tachc_d,~ - ,.. , , · . _27.PRoDucTION TEST Drill Stem. Test #7 Date First Production : I Method of Operation (Flowing, gas Ijft,.etc.) ' "I ' · : : '"' '~ ":' ' "~"";' " :~' ' : ~? "~ ~ " '; ' ' " 'when market is available. ., ..~.. .,.... . · ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL 'CHOKESIZE IGAS-OILRATIO -9/5/81 6 +EST PERIOD I~ 5580 ........ 46/64I , ', Flow. Tubing Casing Pressure. . . CALCULATED. . . . : j~ OIE-B. BL' .. GAS-MCF.,· :.! . WATER-BBL. .. OIL GRAVITY-APl (corr) ' Press. .. .. 24-HOUR RATE .. .," ., , 28. CORE DATA - Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ., - . ~:: :'" ,: , · , 'Core #1' 10,535' - 10,565' - [nterbedded conglomerate, pebbly sandstone, and sandstone.. Series .of fining upward sequences; cross laminations common; porosities'average between 9 and 17%. ~ ~ ~ ,~ '~ll~~D' · Form 10-407 ~1 ~in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gray it¥, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/BELUGA FM 5582 5288 See attached. F/TYONEK FM 8442 8047 Test #7 - absolute open flow - 9165MHCFP0 '. . ,.. 31. LIST OF ATTACHMENTS , 32. I hereby certi~that the foregoing is true and correct to the best of my knowledge Signed Title Drl g. Dept. Supt. DaTe 9/28/8~ -- INSTRUCTIONS General' This form is .designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ,Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completioB), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27~i Submit a separa, te form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none"° STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL ~] lb. TYPE TEST STABILIZED [] NON STABILIZED r-]~ ANNUAL I--] MULTIPOINT F-1'~ ~"- ~" E ~ ~'/~ "'1 ~/ CONSTANT TIME E] SPECIAL [] OTHER /,, ,~ ISOCHRONAL [] 2. Name of OperatQr ' I' ~r'O 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 00~'~ ,~. 81-58 3. Address '(~ka 0il ~ ' O ,/,98] 8. APl Number P; O. BOX 6247, ANCHORAGE, AK 99502 Qaan~_ 5o- 133-20340 4. Location of Well ,~r~,~. --',~; CO/~./~/g~/0 9' Unit or Lease Name " "'~/°rage ~ Cannery Loop Unit ... 2790' S and 2440' E of NW Cor, Sec 4, T5N, RllW lO. WellNumber Eannm. rv Innn Ilnit ~3 11. Field and Po~l ' 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease Designation and Serial No. Wi 1 dcat KB 63' MSLI Fee Leas6 Fredrickson ]6. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 7" 29 6.184 11,125 MD 5818 - 5828 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 5788 - 5796 N/A 18. Packer set at ft. N/A 119' GOR cf/bbl' 120' A'PI ',Liquid Hydr°carb°ns N/A N/A ' ': 21. Specific Gravity Flowing fluid (G} N/A 22. Pro?ucing thru: Reservoir Temp. o F. Mean Annual Temp. o F. Barometric Pressure (Pa), psia Tbg, [] N/A ' Csg· [] ' '' ''' ' 23. Length of flow channel (L) Vertical Depth (H) % CO2 % N2 % H2S Prover· Meter run. Taps 5 · Flange 24. Flow Data ' ·Tubing·Data· Casing Data ' ' ' ., , . . Prover Choke Pressure Diff. Temp. . Pressure Temp. Pressure Temp. " Duration of' Line X Orifice Flow No. Size (in'.) Size (in.) psig hw ° F. psig o F. psig. o F .... Hr. 1. 6.065 2.00" 11.56 ""66' .186t .' 1 2. 6.065 2.00" 21.62 64" ' '1775 ' " ' 1 3. 6. 065 2.00'" "' 39.06' 64 1'654 ' 1 .. 4. 6.065 2 '00" 73.96 63 131'7: '.. 1 ,..~ . ,:?',: ,... ~., . , Basic Coefficient Pressure Flow Temp. Gravity ' Super Comp. --~ Factor Factor Factor Rate of Flow (24-Hour) hwPm Pm Q, Mcfd No. Fb or Fp Ft Fg - Fpv 1. 10.653 76.026 500 0.9943 ' 1 3423' 1,0712 ' 21.36 2. 1 9.653 .104. 496 505 O. 9962 1.3423 1. 0697 2937 3. 19.653 140.45 505 0.9962' 1.3423' 1.0670 3938' - 4. 19,653 192.30 500 0.9971 1.3423 1 0579 5351 · : · . · :' for Separator for Flowing Temperature , Pr T Tr Z - Gas Fluid No. Gg G 1. "' " ; : : : 3. Critical Pressure 4, Critical Temperature Form 10-421 CONTINUED ON REVERSE SIDE Submit in duplicate Rev. 7-1-80 Pc Pc2 No. Pt Pte Pce - Pt~ Pw Pw2 Pc2 - Pw2 Ps ps2 Pr2 _ Pse 1. 3. 4. 5. 25. AOF 1~ 9.65 n ~emarks: . . . I herebv certifv that the foregoing is true and correct to the best of mv knowledge Signe~/~ ~ (~~~/d~ ,.Title D~S~ D~ ~ Date ~0/28/8~ AOF Fb Fp Fg Fpv Ft G' Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing, face were reduced to zero psia. Basic orifice factor Mcfd/-k/hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-x/1/z dimensionless F lowing temperatu re factor, dimensionless Specific gravity of flowing fluid (air--1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water VertiCal depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommenc~ed procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 (- ~d --..J trw 2-. ].:5 ~ 215 § ~ ]..5 ~ 2'.5 3 ~, .. RECEIVEI) Gas {;o~s. ¢or~missior~ Anchorage.. . . PRESSURE CALCULAT I OHS Fi eld Reservol. r Test Date Cannery Loop Unit ,,. Beluga ......... .... 9/5/81 Operator Lease We l I Union, Oil Co. of California _ CLU #3. table 1 ow Rate Stable F1 ow Rate Test (I) (2) (3) . (4). Ps pf (ps2_ pt2} ' 0 No. , , psia ~sia x 104 MCF/D 1 .., 2055 ....... 1876 ....... , 2090' 2 2050 1790 2890 .................. 3 2048 1669 4200 4 2044 1332 ' 5300 2055 , 1145 .,, 5580 ..... Sub-Surface Test Data. ,. · Subsurface pressures measured. S~bsurface pressures computed-'Cullender-Smith :<ethod of IOCC. - (1) "~2) (3) '(4) Test Pws ,: 0 ~,¢: (Pws2-pw~ ) Q No. osia psia X 10-4 1 ' 2355 .. 2]5.8 _ 88 906 2090 2 2349, 2067 ,.. 124.531 2890 3 · 2345 1930 ,177.413 4200 4 2339 1680 264.852 5300 2355 . 1'519, 323.866 I 5580 Nomenclature- Ps = Static surface pressure '~f.__= Flowing surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing botTom-hole pressure (mid-point of perforations) Q : Flow rate, MCF per day at 60°F and 14.65 psia ~E~EIV~ OCT 2 8 1981 Abska Oil & Gas Cons. commission Anchorage "',. -~..~ment. Transmittal U: Oil Company of California unl n DATE SUBMITTED ACCOUNTING MONTH HAND DELIVER 10-20-81 TO FROM Harry Kugler R.C. Warthen Alaska Oil and Gas Conservation UOC-Pouch 6247 AT Commission AT Anchorage, AK 99502 3001 Porcupine Drive Anchroage, AK TELEPHO"ENO. TRANSMITTING THE FOLLOWING: ii CANNERY LOOP UNIT #3' " ~'~"^~ .... J ~ ~ ~ +~ ~ol~ .... ~ng' I u lU~ I i i1~ UilU I gbF lU v bll~ i i UTI I ~ ~ Run ~1' : ~ 2" & 5" DIL ~ 2" & 5" BHC · ~ DIL TVD , ~ ~ & 5" BHC ~ 5" FDC (bulk dentiL:,) ~ ~ r~ ~ ~~ 5" CNL-FDC (porosit~) '~':~~~ 5" dipmeter data ~ dipmeter (comput~d) ~ ~ ~ r~ .~.~. ~ Run ~,, ~ ~.~ ¥ DI L TVD ~,~ ~~ ~ ~ ~ 5:: dipme~er data '~ ~ .~ N ~ 5" cyberdip  ' ~ 5" dipme~er (compu~d) Mudlog (2730' - 11,125') '~ Run ~l' 5" 9 5/8" CSG- CBL-'/DL-Neut-SR Run ~2' b" 9 b/8" CSG-CBL-V]L-GR 1 cpy Water Analyses (5 sheets total) cp9 DST Charts (DST Nos. 1,2 3,4,5,5P,6,7,8,9,10 _. 6 boxes cut & dried lith samples ii FORM 1-2M02 (REV. 11-72) PRINTED tN U.S.A. ll) Robert T. Anderson District Land Manager Union Oil and Gas"-'-!son: We.~tern Region Union Oil Company ,.,i" 2, alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union · 0ctober 16, 1981 Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 STATE OF ALASKA ].981 Permits to Drill Correction of Bonding Information Dear Mr. Hamilgon~ It has been brought to my attention that we have been carrying incorrect bonding information on all Union operated Permits to Drill submitted to the Alaska Oil & Gas ConServation Commission'since January 1, 1981. For each of the below listed wells, Item No. 12 on the Permit to Drill (Form 10-401) should be. changed from United Pacific Insurance Company (B-55372) in the amount of ¢100,000.00 to National Fire Insurance Company of Hartford (B-5534278) in the amount of $200,000.00. WELLS PERMITED TBS A-9 Rd. .CLU'#3 . TBS A-17 Rd. KDU #7 KDU #8 KBU #31-7 KU #34-32 Tungak Creek #1 DATED PERMITED API NUMBER DATED APPROVED 3/17/81 50-733-20062-01 3/24/81 4/20/81 50-133-20340 4/28/81 5/12/81 50-733-20135-01 5/15/81 ,: 6/26/81 50-133-20341 7/27/81 6/26/81 50-133-20342 9/17/81 7/14/81 ~Pending Pend~hg 10/8/81 Pending pending 10/8/81 Pending Pending 10/14/81 Pending ~ E C~ ! V E ~Pending OCT Oil & Gas (]or~s. C. oinnlisSion kncht~','age 1981 Permits to Drill Correction of Bonding Information -2- October 16,~ 1981 We would appreCiate your reflecting these corrections on your copies of the subject Permits and we will do the same on ours. We apologize for the oversite and any inconvenience this has caused. Ail future Permits submitted for your approval will have the current bonding information on them. sk cc: Ann Lannin-LA Office Jim Callender Very Truly yours, Robert T. Anderson RE£EIVEO OCT ~ 0 198! Oil & Gas Cons. Commission Anchorage. Octcber 15, 1981 Union Oil Company of California 909 West Ninth Avenue P.O. Box 6247 Anchorage, Alaska 99502 Res Cannery Loo~ Unit %3, Sec. 4, TSN, RilW, S.Mo, Testing of Gas We! ls This office has received For~ 10-407, Well Completion or RecomPletion Report and Log~ dated September 28, 1981, on Cannery Loop Unit No. 3. Attached to this report was your ragas Wel! O~en Flow Potent/a! Test Reportw for test ~te September 5, 1981. ~eference is made to the Alaska Oil and Gas Conservation Conmisslon ~egulations, Sec~.ion 20 AAC 2S.22§, CAPACITY OF GAS ~LLSo This section spec~fies that testing ks to be at a time requested by the operato= and approve~ by the Commission and reported on Form 10-421, GAS WELL OPEN FLC~ ~OTE~TIAL TEST ~EPORT. This ~s called to your attention for your use in scheduling and reporting futur~ gas well tes~l~. Please submit Form ! 0-421 for this wel t. ]~~,,=e ~ Fc=~ 10-421 ,, ,. ,. , ~ ~ STATE OF ALASKA . ALASKA ~ZAND GAS CONSERVATION C ~ iSION WELL COMPLETION OR REcoMPLETION AND LOG' ¢ · 1. Status of Well Classification of Service Well .. , ,. OIL [] GAS ~] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Union Oil Company of California 81-58 3. Address ~ 8. AP~ Number P. O. Box 6247, Anchorage, Ak 99502 5o-133-20340 4. Location of well at surface 9. Unit or Lease Name 2790' S and 2440' E of the NW cor Sec 4, T5N, RllW Cannery Loop Unit At Top Producing Interval 10. Well Number 2138' S and 1035' E of the NW Cor Sec 4, T5N, RllW Cannery Loop Unit #3" At Total Depth 11. Field and Pool ~Q' S ,,a ~' W nf the NF C_.or Sec .5. TSN. RllW Serial 5. El'e~a~i~n in fee~'('i~di~a~e'KB, DFTetc.)-' 6. Lease Designation an~l No. 63'KB I Fee Lease - Fredrickson Wildcat 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions .~-26-81 7-12-81 9-13-81I N/A feet MSL N/A 17' T°tal Depth (M D+TVD)18' Plug Back Depth (MD+TVD)19' Directi°nal Survey'' '~. I20' Depth where SsSv set. I21' Thickness °f Permafr°stN/A !055c'!!TVD) 111 25MD Surface YES~ NO r--I N/A feet MD 22. Type Electric or Other Logs Run DIL, BHC, FDC, CNL, HUT, CST 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD ':: AMOUNT PULLED 20" 94# Surface 85' 20" 13 3/8" 61 Cf K-55 Surface 2695' 1 7 1/2" 1510 sxs c/ "G" 9 5/8" 47Cf N-80 Surface 8130.' 12' 1/4.', 200.5 .sxs c/ "G" 7" 29Cf N-80 8130' 11125' 8 1/2" lO00.sxs c/ "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and . 25. . TUBING RECORD interval, size and number) _ SIZE DEPTH SET (MD) PACKER SET (MD), None : DST #7 ·. -' ,:!.,,' 5818' - 5828' MD (5497'-5506' TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · 5788' - 5796' MD (5469'-5476' TVD).,.; .;.,.. . S~P attached " , ' - , · 27. PRoDuCTiON TEST Dri 11 Stem. Test Date First Production I Method of Operation (Flowing, gas Ijft,.etc.) when'market is available.I . -' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO '9/5/81 6 TEST PERIOD I~ 55.80 , 46/64I Flow Tubing Casing Pressure CA.LCULATE. D O!L.BBL . GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. COP E DATA Brief description of lithology, porosity', fractures, apparent dips and presence of oil, gas or water. Submit core chips. .. Core #]' ]0,535' - 10,565' - Interbedded conglomerate, pebbly sandstone, and sandstone. Series of f~ning upward sequences; cross laminations common; porosities average between 9 and 17.%. .. , ...... OCT o 2 198~J Form 10-407 ~ll~i~,~:~uplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE . '~;'-" ": ' "'"'~'" ' ' 30. 1 2g. GEOLOGIC MARKERS FORMATION TESTS NAME Ioclude interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/BELUGA FM 5582 5288 See attached. r~/TYONEK FH 8442 8047 Test #? - absolute open flow - 9165MHCFP0 , ............ 31. LIST OF ATTACHMENTS ,,, 3.2. t hereby certi~that the foregoing is true and correct to the best of my knowledge Signed Title Drl g. Dept. Supt. Date 9/28/81 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in !t, em 24 show the producing intervals for only the interval reported in ite~:.27. Submit a separate form for.each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the.,.cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". F orr,'~ 10-407 DATE 8/4 - 6/81 8/6 - #2 7/81 DST #1 CANNERY LOOP UNIT' #3 TESTING SUMMARY FLOWING SURFACE TEST RATE TIME PRESSURE INTERVAL MMCF/D HRS. PS I G * 3 0 3 5.5 1.5 10,530- 10,534 (DIE) Added 10,516- 10,530 Added 10,504 - 10,512 8/9/81 #3 10,128- 10,148 (DIL) 8/12/81 #4 9902 - 9915 (DIL) *Rate too small to measure. 9386 - 9400 (DIL) 0 16 REMARKS Slight blow to bucket. No change. No Change. Reperforated 10504 - 10512 Slight blow to bucket. Reperforated 10128- 10148 Shut-In. Sqz. w/200 sx CL"G" (DST #1 perfs) Sqz. w/200 sx CL"G" (DST #2 perfs) Moderate blow to bucket. Shut-In 1 hr. While reversing out to kill well, recovered sand .' Sqz. w/200 sx CL"G" Shot w/4" csg. guns. Moderate blow. While reversing out to kill well, recovered sand. Sqz. w/280 sx CL"G" OCT 0 2 I98] Alaska 0il & Gas Cons. Commlssion Anchorage Page 2 DATE 8/28 - 30/81 8/31 - 9/1/81 ~..~ 9/2 - 5/81 DST #6 #7 TEST INTERVAL 7194- 7202 (DIL) Added 7230- 7238 6156- 6172 (DIL) 5804 - 5812 (DIL) Added 5818 - 5828 Added 5788 - 5796 RATE MMCF/D 4.6 5.32 'FLOWING TIME HRS. 0.7 0.5 0.5 0.5 0.5 SURFACE PRESSURE PSIG 2100 0 17 600 1600 1150 2092 1233 2066 REMARKS Had 2100 PSI nitrogen cushio No pressure increase after perforating. No gas. POOH w/ drill pipe. Reperf'd 7230 - 38 and 7194 7202 w/4" csg guns. RIHv drill pipe. No gas. Reversed and recovered sand. Acidize 250 gal 7½ HCl. 800 gal 7½ - 1½% mud acid & 250 gal 7½% HCl. S.I'. 1 hr. Final flow.' No gas. Shut-in 1.5 hrs. Reversed out and recovered sand. Sqz w/150 sx CL"G" Had 1800 psi nitrogen cushio No pressure increase. Bled nitrogen to 600 psi. Shut-i to reperforate. No pressure increase. Bled off nitrogen Shut-in 4 hrs. Recovered sand while reverse circ. Sqz. w/250 sx CL"G Had 1600 psi nitrogen cushio No pressure increase. Producing water (68 BPD rate Initi-al shut-in (4 hrs) (Run temp. log) Water rate of 19.2 BWPD. ShUt-in. Run temp. log. AI3~i~ 011 & ~em Oons~, O..omrol$$1oo Page 3 DATE 9/7/81 9/8 - 12/81 DST #7 #8 #9 TEST INTERVAL 5584- 5594 (DIL) 5508 - 5520 (DIL) 5458- 5470 (DIL) RATE MMCF/D 5.25 5.5 FLOWING TIME HRS. 5.75 5.0 0.1 2.3 0.3 2 SURFACE PRESSURE PSIG 1149 2048 1120 2039 8OO 1072 0 1 1551 0 1628 22 67 0 1310 REMARKS Water rate 20 BPD. Shut-in 5.25 hrs. Ran bottom ho]~e pressure buildup. Pe =i ~~ Ran 4-pt. test (See attached data sheet). AOF = 9.65 MMCFPD Equalize 130 sx GL"G" in csg. Had 1550 psi nitrogen cushion. No pressure increase. Bled nitrogen to 800 psi. Shut-in 2 hrs. to reperforate. No gas. Shut-in 2 hrs. Equalize 110 sx CL"G" in csg. Had 1430 psi nitrogen cushion. Stuck wireline tools coming out ( hole. No gas. POOH w/drillpipe to recover wireline tools. Reperf 5508 - 20 w/1538 psi nitrogen cushion. Pressure increased to 1628 psi in 6 min. Bled off nitrogen cushion. Shut-in 1.5 hrs. Charged drillpipe to 1310 psi w/nitrogen and then bled to zero, Reverse circ. and recovered sand, Sqz. w/llO sx CL"G" Had 1290 psi nitrogen cushion. Had pressure increase. Left shut-in for 3 hrs. ECEiVED OCT 0 2 1¢'~ DATE DST #9 TEST INTERVAL Added 5422 - 5435. RATE MMCF/D 0.272 O. 184 0.09 FLOWING TIME HRS.' 6.5 SURFACE PRESSURE PSIG 1310 148 784 119 1239 Page 4 REMARKS No pressure increase. Bled off nitrogen cushion to 10 psi and well started to unload mud. Water rate 916 BPD. Shut-in 1 hr, Water rate 9.6 BPD Shut-in for bottom hole pressure buildup. Pe = 2325 PSIA. Water level + 3350. Final flow. No water production. Sqz. w/150 sx CL"G" GAS WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULATIONS Field Reservol. r Test Date Cannery Loop Unit Beluga 9/5/81 , --Operator Lease Well ~o. Union 0il Co. of California CLU #3 . -- Stable F1 ow Rate Test (i) (2) (3) . (4). Ps pf (ps2_ pf2) ' 0 No. osia ~$ia X 104 MCF/D · 1 2055 1876 . , 2090 ..... · ,, 2 2050 1790 2890 .... 3 2048 1669 4200 4 2044 1332 5300 2055 1145 5580. Stable F1 ow Rate 1-70 Sub-Surface Test Data. .. Subsurface pressures rneasured. S~bsurface pressures computed: 'Cullender-Smith ;,-qethod of (I) (2) ('3) (4) Test Pws 0 (pws2-pw;f 2) Q No. osia psia X 10-4 !',:CF/O , , , 1 2355 .2158 88.906 .. .2090 2 2349 2067 124..., 531 2890 3 - 2345 1930 177.413 420'0 4 2339 1680 264., 852 5300 ., , 2355 . 1'519 . 323.866 I 5580 I OCC. Nomenclature' Ps = Static surface pressure -i~f___= Flowing surface pressure ., Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day at 60°F and 14.65 psia <"" CON'FIDENTIAL CHEMICAL .& GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchor,~ge, Alaska 99509 TE LEPHON E (907)-279-4014 274-3364 ANCHORAGE'INDUSTR IAL CENTER 5633 B Street WATER ANALYSIS REPORT OPERATOR Union 0il Cca~an¥ of California' DAT~ Sept..25, 1981 Z~B NO. 8.991-1~ ~"~LL NO Cannery Loop Unit #3 LOCATION. ~... FIELD .._ FORMATION Beluqa COUNTY INTERVA?~ 8TATF,... _,~J.~k~ 8AMPLE FROM..DS~7~ .],;00. PM 09/0~/8~ after first 2 shots RF. MAR~S & CONCLUBIONg,- ..... ~ ...... 1017 44.25 8~ 100 2.08 ~ ..... 45 1.15 C~d== 16 0.80 C~~ 200 , 6.66 ~am~ha= ..... 2 0.. 16... B~~ 1950 31.98 ~ ....... ~PO :~T~ ..... . Il Il L II I~ L , t~ ~ ~ ~ ....... 2S~ _ ~~ ~_~. ~ ~.~., ~,c~ ~~ ~ . ~~ ~ . . 2110 ' -" ~~. 8.~ .... ~~ ;~ ...... · Oc~ 2 j 188~' ' u o/~ ~.Co~ ~" WATER ANALYSIS PA~E~ ~e a~e d~~ ~EQ ~ U~t ~g Cl 20 Na HCO~2 Ca SO, 2 ~g CO, Fe 2 Cl HCO., CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TELEPHONE (907)-27g-4014 274-3364 ANCHORAGE' INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPE~ATO~ - . Union Oil of California W~LL N° Cannery ,Loop Unit ~3 COUNT~. STATE . , Alaska DAT~: Sept. 25. 1981 ~AB NO. 8991.2 LOCATION ......... FORMATION B~luga _ . _ . . . , .. INTERVA?- SAMPLE FROM...,. DST#7; .'1,2:"36 AM 0,~'/65_/81 Strawberry Tests ~S & CONCLUSIONa: 781 33.97 365 9.34 32 1.60 "' '' 4.0 .... 0'.L33'' _ ,1, ,~ - [11 , , ~ 111 , i Obe~re~ pH .......... 45.24 2637 - 2159 -' '7.6 Sulb~ ...... 95 1.98 Chlort~ ...... 400 .~_ 11.,28 _ C,zbo~te ..... 0 ' --- a~~ ..... 1950 '3~. 9~ ' H:,dro:,m, ..... --- _ ---_ .... 45.24 . .. _ ,~ ~ ,,,, .... , , , 3.0 3.1 WATER ANALYSIS PATTERN ~L~mple above de~'n'bed MEQ l~' ~g Cf 20 Na HCO, Ca 2 S04 2 Mg CO, Fe 2 Cl HCOs' SO~ COs CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TE LE PHONE (907)-279-4014 274-3364 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPZHATO~ Union Oil of California ~LL NO. Cannery Loop Unit $3 COUNT7 ~TAT'~ ., .~aska DATm SeDt. 25, 1981 L&B NO. R991-q~ LOCATION FORMATION ~ Be luga INTERVAT- SAMPLE FROM .... DST%7; 2:55 PM 0~/05/~1 , Last flow period of 4 point CONCLUSIONS: ~ ...... 820_ .~ . _ 35.67 ~ ..... 310 7.94 Clk~m 12 _ 0.60 ~ ..... 3.0 0.28 8~ ...... 35 ~ 380 . C=~ . 180 B~a~ ..... 1650 · H~~ ..... ..... 0,7-2 10.72 5.99 T~ Ca~ .... 44.49 ?~ ~ .... 44.49 -' ' ii lllll I II ! , I Jl 3111111 ! J LJJ IlI I t i ~ I~ii, 'm, ~l, I m m ~ I aL T~ ~ ~ ~I ..... 2553 S~ ~ ~ ~.F.: NaCI ~~ ~1 ....... 2217 O~ 3.0 ~~ O~ ;H .......... 8.6 ~ .... 2.0 .~ ~~ WATER ANALYSIS PATTERN Sample above d~ncribed ~EQ ~r Unlt Ha C1 Na 20 HCO, Ca SO. Mg 2 CO, Fe CI HCO, $O~ CO, CHEMICAL '& GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 TELEPHONE (907}-279-4014 ANCHORAGE INDUSTRIAL CENTER Anchorage, Alaska 99509 274-3364 5;633 B Street WATER ANALYSIS REPORT -Opz~aTo~ Union 0il of California ~ NO. Cannery L.oop unit #3 FIELD _ COUNT~ Alaska DAT]e Sept. 25, 1981 ZAB NO. 8991-4 LOCATION .... FORMATION Sterlinq, ZNTERVAY- SAMPLE FRoMDST%9; 11:30 AM 09/~!/8!_; Initial flow period CONCLUSIONS: Ikx~=m ...... 589 25.64 ~ ..... 42 _ 1.08 Cm3¢{=~ ....... 6-0 . _ 0.30_ _ ~ ..... 1.0 , 0.08 . Sul~a, ...... 110 2.29 Chk, F~ ...... 310 8.74 C.m~'~ ..... 200 - 6' ~.6 B~ba~a~ ..... 0 --- Hm,d~ ..... 160 ...... 9.41 ?o~ Auk~ .... 27. I0 o~w, __ 3.3 eam.~ Calcalat~ .... 2.4 eh~-~ WATER ANALYSIS PATTERN 8ampls atmve de~n%ed ME(~ p~ Unit N~ Cl 10 Na HCO,1 Ca SO4 1 Mg CO s Fe 1 Cl HCOs SO4 CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 TELEPHONE (g07)-279-4014 ANcHORA'GE INDUSTR"i~L'CENTER Anchorage, Alaska 99509 274-3364- 5633 B Street WATER ANALYSIS REPORT OPZ~t?OR Union gil of Califorb/a W~LL NO. Cannery L,.oop Unit ~3 FIELD COUNTY 8TAT~ . Alaska DAT SF~tit;., 25. 1981 LOCATION FORMATION S ter 1 inq INTIJRVA?- 8AMPL~ FROM.., DST#9; 1:30 PM 09/11/8i 1~~8 & CONCLUI~IONS: . Zod~m ...... 494 21.50 ~ ..... 30 0.77 Cakim - - ,!2., ,, 0.60 ~ ..... 4.0, ., 0.33 ?o~ Ca~ 23.20 ~J, ~l , ,, , i ,. , ................... Toed ~ solk~ ma/l ...... 1280 NaCl J~~ m~/t 1262 O~d pH .......... 8.7 · , ,., III I I i I III sut~ ...... 45 Chlo6~ . . 170 C~b~ ..... 180 7OO 0.94 ,4.79 5.99 .~,11.48 _ _ .... 23.20 5.0 ~~ 5.1 ~%~~ WATER ANALYSI~ PAI'TERN 8ampl~ above Illl-lllllllll llllltl]lllll IlllllllllJll lllllllllllll Jllilllll[lll I111111I llllllll~ IlllJlllJJJJJ I.Illlllllll,ll llllilll'lllll !111111Ii11]1 Jll JJlllJJ[ ,,,Il lfllll'lllllll lllllilllIII! LJlllltiJ£1J] IlIJTlIllilli IIIllllllJlll lJlilllllllll lllllllllllll llllllIilllli IIIlilIlllllI II[lIl]llJl[! JlilllJJllJil lllllllllllll Jllllll]illll lllillill~ llllilItJ/~J~ llllllllJlflJ Ill'lllltillll llll_lll_llJlJl fllillllJJ[[[ IllllllJlIlll lll[[llllllll ll[[lJlllilll lllllllllll, l[ MEQ p~ U~tt Cl 10 Na HCOs Ca 1 S04 Mg 1 COs Fe 1 Cl HCOs COs ,(;CIENTIF!C r)RILLING CO~TROL$ 1111 E GYROSCOPIC OIR:,~CTT. O.~AL SUPVEY FOR Jg.g ~ U~4 nE ~I: 5 2 5 5 WELL ,~Z~'~3: CAN~TERY LOOP ~! 3 SURVEY D~TE: '7-20-81 SURVEY Eb~GINi,~ER: P;qlL GRAPET GYRO REFt~RucNCE BE~RINg: N00-00E ~dETHOO OF CALCULATION: RAOIU$ OF CURVATURE VSRTIC-~L qECTIDN CALCULATE.O IN A PEO'.POqlL :)IRECT[O.,'.] O.w: H 67-13 W COM.~ENT.q.: T~{ ANK 'KOU *TF{IS SURVEY IS CORPECT T',)THE * *SUPPORTED 'DY ACTUAL FIELD D~T.~.* * COMP~,IY RE PRES~{~P~TI VE * *********************************** %255 DE PTq $ .[3CT. COIJRSE O:3V. SCIENTIFIC DRILLING CONTROLS 11!1 E 80TH INqUN SUP, VEY BY RADIUS OF CURVATURE INC P,E A R i ~',]G DATE: PER 100 7-20-81 ST ATI ON ,D IST ~.NCE P~GE 1 OIS PLAC EMF. NT 8 E.AR I,~ !00.0 20,q .0 300.0 400.0 500.0 70 8O '.) 0 10"3 0.0 0.0 O.0 0.0 1100.0 1200.0 1300.0 1400.0 1500.0 160 ].70 180 190 2O0 0.0 0.0 0.0 0.0 0.0 100.00 200..00 300.00 400 .oo 500.00 500.00 700.00 900.00 900.n0 999.99 1099.~7 1.!99.37 12q2. 30 1396.82 14q5. 1593.0'0 16n0.26 !796. ].4 18'8.0.90 1975.02 O. o o 0.00 0.00 0.0O 0.00 0.00 0.00 0.00 0.00 1.31 6. 15.76 33.1P, 47.20 65.55 85.38 108. '77 136.82 168.32' 201.63 0.00 0. 0.00 0. O0 0.00 0.00 0. 0.0 O 0.00 1.31 4.80 04-00 ~_! 77-56 9.80, 07-15 N 74-29 14.56. 09-30 N 75-02 17.15 10-15 N 72-25 18.a.4 ll-00 N 73-15 19 .q4 23.55 28.40 31.94 33.79 12-00 ~ 72-52 W 1.5-15 N 75-15 W 17-45 N 77-08 W 19,30 N 75-11 W 20-00 ~ 77-40 W ri. OD N o.o0 E 0.OO 0.00 N 0.00 E 0.00 0.00 N O.0O E 0.00 0.00 N 0.00 E 0.O0 0.0O N 0.00 E 0.00 2.06 N 5.73 W . 2.56 4.40 N 15.25 W '4.2'7 8.10 N -29.33 W 2.25 12.76 N 45. 83 1;,7 0.97 18.21 N 6.3.45 W 0.77 24.-02 N 32.52 30.49 '~ 105.17 37.25 ~] 132.74 44.63 N 163.82 52.28 N 19~.73 1.00 3.30 2.56 1.7S 0.71 1. 31 ~T N 65-14 W 203.56 :~'i' ~ 75-07 W 2100.0 206,9.91 235.71 34.41 20-15 N 72-06 W 61.25 'g 229.94 W ]..93 JOB ,.,UMBER: DEPTH 5255 VE RT. DE PT ,q VE RT. C OURS SCIENTIFIC ORILLT. NG .CO.qTROLS 1111 E 80Tq f) .'4 SURVEY ,BY PA,.OiUg OF CURVATUR~ BE AR. lNG CO ORD INATEq .... TUR,., D tl LAT ITUDF, ,nE P..q P ', ~' DhTE: 7-20-81 O-LEG PER I00 ST ~.TI ON DISTANCE ..% PAGE 2' DI SPLAC E,4 ~?.N? '2 200.0 2300.0 ~400 0 2500.0 2500.0 273'.3 2800 29 00 3 O 00 3100 .0 3200.9 3300.0 340 0.9 3500.0 3500.0 ~70 390 390 4OO a ].0 0.'0 q.0 0.0 0.0 O.O 2162.2 2255.3 234.,3.7 2a42 .! 2535.3 2628.9 2722.7 28].5.4 2907.0 2999.5 · · 3 3 3 3 3 ~92.5 184.5 275.6 366.5 457.3 548.3 639.8 731.3 822.9 914.9 7 271.51 35.84 9 307.:83 36.45 4 343.52 35. 84 0 379.22 35..84 8 415.00 36.04 7 44,-9.89 35.22 9 484.18 34.61 1 523.. 43 37.56 3 560.93 40.07 3 599.09 3'7. 86 ,534.27 36.85 672.85 39.2} 713.10 41.07 754.02 4]..57 795.86 42.06 0 837:31 41.47 3 ~77.57 40.27 6 ~17. q3 40.27 · 9 957.85 ~0.07 4 997.07 39.27 21-45 21-00 2 i-00 21-00 21-15 ,.' 0-00 20 -30 23-45 23-30 21-00 22-15 24-00 24-30 24-45 25-00 24-00 23-30 24-00 23-15 23-00 ,~.~ 53-19 W 74.83 'N 263.06 ~.~ 61-31 w 91.69 ~ 295.3'7 N 62-38 w ~ 108.'16 N 327.04 N ~i-49 W 125.16 N 358.75 N 58-.19 W 143.00 ~ 390.06' N 59-51~.W 160.97 W 420.35 N 5.9='03"~% ~/'178.56::'''N 450.!6 q 58-22.'W: ~;'t198:;'12 N 482.34 N 562'39~ ...219..64.N 516.1& ~ 5 5--4 ~ w ~:'~ 4 o< '7'3..< ~ 5 47. ~ 9 56-49 W 2,.51.20 N 578.23 W 56-08 w 282.89 N 610.97 W 55-22 W 306.00 N 644.~2 W 57-20 w 329.09 N 679.60 W 66-33 W 348.86 N 716.$9 W '70-20 W 364.0q ~'~ 755.25 W 65-54 W 3'79.10 N 792.61 W 65-06 W 395.80 ,N~ 829.26 W ~4-18 W, ·412.93 N 855.49 W 63-40 W 430.15 N 900.78 W 3.48 0. q9 0.3..9 0.29 1.11 1.30 0.57 3.26 0.73 2.53 ]..32 ,'1.77 0..59 0.86 3.88 1.86 1.85 0.59 0.82 0,35 $',50.93 ~T .~ 66-57 W 958.95 ~T N 64-30 W 4200.0 4006.99 1036.08 39.07 23-00 ~ 64-14 W 447.31 ~] .935.98 J'O~ Mb~tBE.R: 5255 COURSE I~C DEV. D M PAGE SCIENTIFIC ORILLI.MG CONTPOLS 1111 E 80TH DATE: 7-20-81 SURVEY BY RADIUS OF CURVATUPE BEARING D M COORDINATES O-LEG ~ LATITUDE DEPARTURE ' PER 100 STATIOq DISPLACEVE,~]T DISTANCE BEARI .%lG 4300.0 40q8.87 ~. 4N ~. 0 4100.75 4500.0 4282,80 460~].0 4370.94 0700.0 ' 4467.16 4200.0 455Q.0.4 aqnN .0 ~650.57 5ONO.O 47/12.!0 5100.0 4833.8~ 5200.0 4925.94 1075.51 30.47 23-30 ].l14,ql 3qi~. 7 23-00 1153.91 39. N7 2.3-00 1192. 73 38.27 2 2- ~.5 1233.. 38 38.67 ~-45.. . 1270. ~ 7 3'q. ~7 23-45 13,qq. 83 40.27 23-45 13~.9.21 40.27 23-4% 1389.06 39.67 23-00 1426.27 39.07 23-00 530~.0 5012.16 1463 5400.0 51!N.3g ].501.55 5500.0 52N2.52 1539. ~3 5600.0 5204 .qO 157~.,63 5700.0 5287.5~ ].61.3.34 5800.0 5480.1~ 5900.0 5572.Qq 60nfl .0 5665.6q 6].0,q . 0 575R.~q '6200.0 5851.77 165'0. ]4. t6~6.5q !'723.42 1760.03 17~5.53 3q .67 22-30 ~8 67 0 3-00 38.87 2 2-4~ 3R.27 22-15 3?.66 22-00 37.56 22-15 37.26 21-30 37, ,~-~{ 22-30 37,26 21-15 36.04 21-qO 64-22 w 63-06 W 64-36 w 63-48 w ~0-23 W 7q-43 ~W 78--5 3 79,.33 ..W 8!.-04 w 20-10 W 80-16 ~ 21-15 ~.,7 70-00 W · ,90-00 'W 7q-16 w 77-20 W 72-26 W 75-47 W 35,24 21-.00 N 76-00 464.43 N q71.45 W. 0.50 421.~0 ~ 1006.25 W 0.71 499. 12 N 10.{1.92 W 0.59 515.04 N 1076.92 W 0.40 531.08 g 1112.52 W 2.54 5~1.03 :g '1150.58 w 3.61 <.<.~-~8,8.!-~t:~,' 1.].90.17 W 0.21 . 1 2 .74 w z 6$.s8 w o.75 ,.%:5 7,1%(!:.5 [..~: 1307.0~ W 0.21 577.66~'N 1345.19 W 0.77 58'3.97 N !3q3.34 W 0.61 5.90.57 k] 1421.65 W 0.25 596.72 N. !'459.42 W 0.63 603.1~ N 1496.53 W 0.82 610.04 ~ 1533.56 ~0:~ 0.45 617.'07 ~ 1570.15 W 0.99 624..Qe~ ~<~ 1606,76 W 1.06 632. 80 'N 16~3,19 W ]..32 640.84 q 1~78.31 W 0.99 609.58 ~ .1713.07 W 0.08' 1349.71 ~T N 65-40 W 1724.03 .~T .t,1 69-45 W · 3©B N%~BEP: 5255 - ,, qE'PTq 6400.0 6038. 6500.0 6131. 6600.0 6225. ,5'700 . 0 6318 . 6200.0 6412. 69oo .o 7000. O 6600. 7100 .~ 6694. 7 2(]0. I] 6788. 7300.0 6282. 7400 .O 6977. 7500.0 7072. .7600 .O 7167. 7700.0 7267.. 7800.0 7357. 7909.0 7453. 8G00 .O 7549. 21flO.fl 764'd. 8200.0 7740. !7300.0 ~/236. 2400.0 7932. 49 84 72 38 05 r) 2 21 47 95 58 27 54 11 8'?.. 69 94 VE PT. '3 ECT. 1885.39 1901.79 lq37.20 1972.23 2005.83 20~1. ,.i~ 2075.27 2105.52 2141.72 2].74.37 2206.55 2238.54 27,6q-. 77 2300.03 2359.50 23~8.70 24.17.50 2446,09 247~ .04 2'501.12 COURSE DEV. 35.84 35. 8'4 35.8q 35.43 35.02 35.02 34,2 O 33. %9 33.38 32.76 3'2 .35 32.14 3]..32 30.28 29.86 29.65 79.2/1 28.61 27.9~ 27.14 ) '.qCIENTIFIC n. RILLING CO,NTROL$ 1111 E .BOTH IN.PUN BURVEY .BY .P. AOIU$ OF CURVATURE I,NC O "4' C~OPO IN~TE$ LATITUOE DE PARTURE 21-00 21-00 2.1-00 20 -30 20-30 20-30 1_9-30 19-45 19-15 19-00 18-45 18-45 17 -n% 17-30 17-15 1.7-15 16-.45 16-45 15-30 16'00 15-30 N N N N N N N 75-45 76-26 75-43 75-57 7.,:6-16 75-37 75-5.4.' . .. 7/37-14 73rF3 -.W '72-58 W :72-43 ~:,'/ 6q-45 W 6q-30 [,7 69- 15 W 69-57 59-41 69-26 69-]_2 70-52 71-3 5 658.32 N 1747. 82, W 666.94 ,N 178'2..51 W 675.56 N 1817.39 W 584.23 N 1851.74 w 692.64 M 1~85.74 W 701.15 .: 709.5..q,.f] [~:" '728 ~('19 C :; 3.'7',~, 7 t ,'~ · 747.12 '156.6 0 766.68 777.2 2 787.'74 7c~8.08 808.16 q 818..2 3 N 828.33 ~..1 837.89 q .. 846.5 2 N 1919.71 1952.-86 ].9.85.24 2017.1~ 2048.53 2079.48 w 2110'19 W 2139.84 W 2168.22 ['.~ 2196.17 W 2223.97 2 251 ..4i 2278.41 2305. l~ 2331.48 2357..18 DATE: O-LEG PER 100 O.Oq 0.24 0.26 0.51 0.11 0.2~ 1.00 . O. 93 0.51 0.26 0.26 0.0~ 1.36 . 0.26 0.26 O. 21 0.51 0.07 0.26 o. 6S PAGE 4 7-20-81 ST RTIOq DISPLACEqE,NT STANCE BERRING 2fl77.78 AT ~ 70-02 W 2392.05 AT N 70-15 W JOB 5255 VE ~ T. ~ PTH 0500.0 ~600.0 8?00.0 8800.0 a90O.0 qOOO 9100 · o, 200 .. 94 0O .0 .0 .0 .0 qSO0.0 95'00.0 9.70 O. 0 °B O0.0 9900 .O 10000. 10!00. !920.n. 1C'390. 10 400. 802a 8126 8.~0 8319 84.].5 9513_ 8607 8703 8799 q9o, 0. 9085. 9!91. 9276. 9372. 946'7. 9563. 9650. 9754. 9850. .42 .20 .5.6 .62 ..63 .4=, .08 .71 34 90 34 47 98 4'n 23' 87 SECT. 2527.35 25 53.18 2579.05 2604.03 2631.65 2~59.40 25 97.3 3 2715.85 2744.97 2'774.01 2893.03 2832.30 2861.96, 2991.37 2920.33 2940.69 2'978. q4 3007.27 3035.52 3043.28 COU R SE .13 E V. 25. 25. 25. 25. 26. 27. 27. 28. 79. 29. -SCIENTIFIC ORILLI~IG CO.~TROLS 1111 g 80TH INRUN SURVEY BY RADIUS OF CURVATURE Is.C BEARING 30 15-00 8,5 15-00 88 15-00 88 15-0 0 72 16-00 77 t6-15 98 16-15 6 1 1'7- q0 24 17-00 24 17-00 29.-24 17-00 29.45 . ].7-15 23. 86 17 - 30 29.55 17-00 29.24.. 17-00 COORO I~qATF.:S LATITUDE ~)EPARTURE 2q. 29. 29, 28. 854.99 N 2382.12 863.59 N 2406.53 872.77 q 2430.73 882..4.6. N 2454.72 893.19 N 2.479.19 nO4.8q ¢1 al7.21 N ., :6'2~ 33 '""W 61"I 8 59'~.5.9/: W :':'" 0'58". '4.4 ~'1 "": . "':"'"" 60-37 W 972.92 N 61-13 W 9~7.23 59-55.W 5'7-14 W 65 ].7- 33 65 17-00 82 16-3:] 82. 17-00 -40 16-00 2504.38 2529.51 2554.93 2580.72 2606.21 2631.50 W 2657.33 W '1001.91 ~.l 2583.3~ W 1016.85 N 270q.96 W 1031.73 N 2734.13 W 5R-53 56-50 56-28 5 5-10 54-49 1046.97 1062.75 1078.5 9 1094.7q 1111.0,9 2759.,5~ W 2784.67 W 2808.74- W 2832.58 W 2855.84 W O¥~g: 7-20-81 r)-L E3 PER 100' 0.50 0.39 9.31 0.31 1.16 0.26 0.75 0.37 0.3,9 0.19 0.31 0.46 0.51 0.10 0.51 0.79 0.51 0.62 1.00 ST:AT [ ON . OI$ Pll ACEM F. NT I ST ANCE BEARI ~G 2662.85 AT q 70-0S W 2051.50 P~T q 69-13 W 10590.0 q'947.12 3099.72 27.14 15-30 N 53-30 W 1126.97 N 2877.8'5 W ' 0.61 525 5 ,D E PTq r)E P'l"4 VE P,T. q 5;CT. 3115. 31 3t40.0q 3t. 6a .22 3i,q8. ].5 3212 .04 qCiENTT,.m !C f3 [~I LLI~' 111l E S0Tlq CC)rlRSE DEV. I r,] P, U~ qURVEY BY P~r~IUq OF CrJRIi~'PURE IxIC BE~IP I~,IG [3 ",4 D ~.~ C.c) ©90 IN Aq2' EE L~ [l'I TUDE [~EP ARTURE 28.30 15-0,9 t>l 54-07 W ],1~2.50 N 7.899.09 25..4.6 !4-3~ N 53-46 W 1157.z1.9 ',~ 291q.56 2-4...8B 1~.-].5. 'q 53-24 W 1].72.23 5I 2939.6~ 24.52 -~14-15 N 54-00 W 1iq5.80 N 2q59.47 24.52 14-15 x] 52-37 W 1201.51 N 2q79.21 -- , PRGE 6 OA~.PE: 7-20-ql , O-LEG STATION DI SPI,.AC'E~ E: PER 10 C} D I ST ~%NC B ~EAP, 0.53 ,q.51 O .27 0.15 0.3~ 3212.37 AT ..',~ 68-02 W " ~,"~i~k~0il~L0-?~t~i~i~leson NO CLU #3 ,,.,AGE' eei ___ WEI,I ....... · 'f:SI,D Wi 1 dca~'"~'J~ ' ' f m ~OCAT1ON_2451]Z_&__PJg_0]JLiEgJ_~he SW cor. SFi L::;£T A " PAGI'.; l~!O. 1 . ~- .i · '-- ~ .... ' "~'__91] 3/81 ,SPUD DATE 5/26/8l . COMP. I)A i.,. . CON'FItAC'I'OI~. Brinkerhoff Signal Co. RIG NO.59~__ TYP:;: UNIT 0ilwell 860 · Sec, 4, T5N, RllW, 'SM. DHH..,L PIPE DESCRIPTION .... - ....... w,vrz , ..... -~-~- ~-~.~ .... 50 133 20340 g T TO OCI,'AN FLOOR I Fl.CO~ ! -,~iiMIi iq@. mi-o@_ ____SERb~L NO. uu-I___-CVO~ .' ' ~ '" ' ~'D j1.125' ..... TV D _ ]J552' ' ~L ~ TO MSL , ~~- ' ~']'l ..... , .._= ..... 2~,,, , ~26AiN'of ~~-- · Il T' ~OID UI,L DECK . ] ~ ~ ~O II :'N~' L .... . · · -- } -- N !~ t ..... I . __ ... ..... . . t~I IlO~~VED. ,,w~~,~4~~~___,-~ _ .-i3 3/8' , 61# Buttress K-55 9 .5./8' 47# Buttress N-80 . 7 .29# . Buttress N-80 .. 2695" --cmt'd w/ :i-5-10 sxs cmt. 813d; Cmt'd w/ '2005 sxs cmt. '., ll125', top,0 7783' Cmt'd w/ 1000 sxs PERFORATING' RECOIID _Z~i1/8] 9936-~9938' 10998__ (FC) '~ BS #1 .1 SqZ,d w/ 100-SXs cmt.:thru r6-t@ 992z 7/22/81 9898-9900' 9922' (ret) j BS #2 'i Sqz'd W/ '250 sXs cmt thru ret @ 9850' 7~23/81 9408-9410' 9850' (ret} -BS #3. ' -~ S~Zi'd ~/~-~ ~ ~ ~-~ ~ ~ ~ 7/,23/81 9372-9374' 9388' (ret) BS #4 SqZ'd w/ 550 sxs cmt thru ret @ 9270' .:8/~/,8l 10.5,30-105341"- 10~98'l(F,C,) -DST #l ........ -----: ...... lfl_~16_ll01.~.~ ....... II. III { . No prod. - Sqz!d thru ret @ 10391' w/ m I " iI0S04-10512' IIII II ,, ) 200 sxs cmt. . . R/~/A1 lfl~fla-lF1R1 ?' lOC)qB' (FC) " " / -' ,i'-' i6i 8-i6i48' ,,III' DST'I'I'#2 ) No Pirod. - Sqz'd thru Pet La iOOZO' w/ - " 10128-10148" ' ~ 200 sxs cmt. 8/9/81 9902-9915' 100~0' (r~t DST #3' '1 No prod. -.Sqzid thrm ret @ 9775' w/ 200'sxs cmt. ~_/12/R'l q386.-9400' 9775' (re~) DST #4 m I No prod Sqz'd thru ret '@ 928(J' w/ 300 sxs ~mt ~/13/81 7246-72481 9280' iret} BS #.9 Sqz'd W/ 250 sxs cm{ thru ret @ 7222' -- ~/15/81 7187-7189' 7222' (ret) BS #10... Sqz'd w/ 250 sxs cmt thru'ret '~ 7109! -~-- . ~_l. 6,/F~ll617E-6'177' 7109' (ret) BS #ll Sqz'd w/ 250 sxs cmt thru ret @.6131' 1/.16/al ~09i-6093' 6131' (reti BS #12 I Sqi.z'd w/.250 sxs cmt thru ret @ 6040' ~/17/R1 .E7Q~-E7QR' 6040' (ret~ BS #t3 r]> i'/~/al ~9-_~83a_'- .... 6nan'_.~ti " " _.L~.~J~nl:~J_d~L_l~sxs c~t th__ru ret,, @ 5815' DATE INITIAL PRODUCTION IIITEEVAI. NET OIL C.P. T.P. CI¢Oi<E TYPE: CAMFRII.~ TP0N WORKS CASING HEAD: 75" 2000 psi SOW - CASING HANGER: 20" X 'l 3 3/8" flow-thru' bol 1-weevi 1 type ' CASING SPOOL: 20~' 2000 psi X 13 5/8" 5000 psi "wf'; ' TUBING HEAD: 13 5/8" 5000. psi X' i0II 5000 ps] "DCB" spool W/ 10I' 5M bli'nd'flanqe TUBING tIANGER:_ TUBING IlEAl; .TOP' MASTE){ VALVES: CHRISTMAS TRF. E TOP CONN.: .... Lec-cs.e_.- FredricksonV/EI,I, NO..._CLU.~_~ ,D..~l~at ~OCA'iUON~~.~ & 2490'N fr_~_ the SW corner, Sec. 4, T5N, R]IW; SM ..... $1-1 F.'i:'T A Co. RIG NO._ 59 DRII...L P1PiC D,,,oCt,IP'flON. >Ei'~l~T.I'i' NO81-58 SERIA.L NO. 50-133-20340 · - r~ [.D .... 11125' i.V.D. _]_0_552 ' :)EVIATION (B.ILL.). ]?O?'N _~ ?g79'W of gmJrfacp JOMPANY ENGINEER .. /~PROVED: . · ~-;~~~~~= _ ~, _ .... .~ ........ ~:~_~.~,t~ - - . CA S!~J.G_&T~f¢!!~fG IlECORD SIZE WEIC. HT THRE~D GRA DE DEl)TI[ ELI-'WATIONS: WA'fEI[ 1)ICPTiI iR.T. TO OCEAN FLOOR I1. T. TO ,~,i LLW II.'1\ TO DRI[.L DECK R.T. TO PROI3UCTION DECK PERFORATING RECORD I/.18/81 5779-5.781" _ 5815' (ret) BS #14 Sqz_Id w/ 300. sxs cmt thru ret @ 5720' ~/18/81 5601-5603' 5720' ,.(.ret) B.S #15 Sqz'd w/ 250 sxs cmt thru-ret @ 5585' ~/19/81 5565-5567" 5585' (ret) BS #16 Sqz'd w/ 200 sxs cmt thru ret @ 5484' !/'19/81 5412-5414' 5484' (ret) _ BS #17 Sqz'd w/ 200 sxs cmt thru ret @'5394' '. ;~.L 7194-7202' 7770" (ret) DST #5A' [/_29Y_8]_ 7230-7238' ". " #5B[ No prod. - sqz'd w/ 150 sxs cmt thru .. .- ;/29/81 7228-7238' " "- 5C [ ret @ 7092'. . [/29/81 7192-7202' " " 5A 1 ~31/81__ 6156-6172' 7.'092" (ret) DST"'#6 ~ No prod. - sqz'd w/"250 sxs cmt th'ru " 6156-6172' " '' "reperf~ ret @ 6050'. ~/2/81 5804-5812' 605~' (retl DST #7A !) - I/2/81' 5818.-5828' " DST .#7B'I~ Had prod: - cmt'd W/ 130 sxs cmt f/ _ [/3/8! 5788-5796' ,, nST ~7£ )' 59'55 to 57.62' _ ~/7/8! 5584-5594' 5762' (cmt) DST #8 ~ No prod. - cm~'d w/ 110 sxs cmt f/ .... _" _55B4--~bq4' " "reperf ~ 5761 to 5555'. ~/8/~! 5.~n~-.~.~?n' .~.~.~.~' (cmt) BST ~qA ~ No Dr@d, - sqz'd w/ 110 sxs cmt t'hru _ I/q/R1 .~n~-_~_~?n' " "qA'rener~ ~et @ 5493' ,~)~_8.1 5458~5.470' .... 5493~,t), .... D.~ST_T_. ~.9.;B.' ___~._~]50 sxs cmt thru ret @ 5300'__--__. }/ll/.81 5422-5435' " ~ · ~, P,.,~. D U(,'I ION' DATE IIITERVAI, NET OIL TYPE: _ , CAMERON IRON I~ORKS W E_L.L H_F_,.AD__~_SDJE_I!I CT:rOi-CE .I R E. Jfl.~JU.(,S , , · j_C.F G oR CASING HEAD:~ .... 20.00...4~sl_S0 CASING HANGER:__20" X..._13_3/B". flow-thru be'Il-weevil type CASING SPOOL: TUBING HEAD:~ _ 20" 2000 psi X 13 5/8" 5000 psi "wf". 13'5/8" 5000 psi'X 10".5000 ~si "DCB" sp6Ol 'w/ 10" 5M blind flange.' TUBING IIANGER:_ TUBING tlEAD .TOP' MA STER VALVES: C 1-I 1X I ST ~.r A S 'Fil lqE TO P CON N.: .... LEASE U['IIO t GIL CO';PA h' OF CALIFOPJiIA 'ELL RECOPJD FEE LEASE - FREDRICKSON ~;~JJ.J_ [.~0, CLU #3 FIELD WILDCAT D:FFT D PAGE ik), ...1 DATE DA! ~ Y COST: ACC COST: AFE B 5/22/81 DAILY COST: ACC COST: AFE J~MT: C 5123181 DAILY COST: ACC COST: AFE AMT: D 5/24/81 DAILY COST: ACC COST: AFE AMT: DAILY COST: ACC COST: AFE A~I': DAILY COST: ACC COST: AFE AN2F: ETD $ 440,564 $ 44o,s64 $2,813,000 20" D. 85' 67 PCF 305 SEC $ 22,234 $ 462,798 $2,813,000 20" D. 85' 67 PCF 305 SEC $ 35,80] $ 498,599 $2,813,000 20= D. 85' 67 'PCF 305 SEC $ 19,406 $ 5]8,005 $2,813,000 20" D. 85' 6'7 PCF 305 SEC $ 26,512 $ 544,517~ $2,813,000 1038' / lO05' 20" D. BS' 68 ~I:F 80 .SEC 55,353 599,870 $2,813,000 DE-J"~AILS OF OPERATIOIIS, DESC,RIPTIOI!S .& RE. SUL, T.S Commenced rig up on CLU #3 @ O0:O1 hrs -5/21/81. Set sub-base. Put derrick to- gether and pinned to floor. Installed .jrawworks and 2 rig motors. NOW: Continue rig up. .Spotted mud pits and support houses. .~.Installed mud pumps. Strung up blocks. Revamped lines to FPS unit. , Rigged up and raised derrick. Rigged up mud pits. Broke tour @ 12:00 hrs 5/23/81 Filled mud pits w/water. Picked up Delmag D-22 drive hammer and drove rat hole. Installed 20" guides and drove 20" 94# plain end drive pipe fitted with inside drive shoe to 85' RKB (57' of soil penetration). Had refusal of 340 BPF with gradual increase for final 7'. Cut off 20" pipe 3.25' below ground level. Installed CIW 20" 2000 psi csg head. Installed 20" 2M Hydril w/ 6" relief line. Mixed gel-Benex spud mud. NOW: Complete rig up - prep to spud. Completed rig up. Spud well @ 02:30 hrs 5/26/8T,. Drilled 12 1/4" hole f/ 33' to IOOD'. Circ and dropped survey- 1/2°. POOH. RIH w/ bit #2 on BHA #2 .for .D~vna-drill run #1. Oriented D/D - could not break circ. POOH - found float instal led upside down. RIH w/ D/D. Oriented tool and directionally drilled 12 1/4" hole f/ 1000' to 1038'. NOW: Drlg @ 1038'. . LEASE DATE UNION OIL CALIFOP ' IA . FEE LEASE - FREDRICKSON S ;EET D PAGE ih, -..2 ELL RECOP2 2 5/27/81 _~'.iEI_L I~O, CLU #3 FIELD WILDCAT DAILY COST: ACC COST: AFE AMT: 3 5/28/8' DAILY COST: ACC COST: AFE AMT: 4 5/29/81 DAILY COST: ACC COST: AFE AMT: 5 5/30/81 DAILY COST: ACC COST: AFE AMT: 6 5/31/81 DAILY COST: ACC COST: ' AFE AMT: 7 6/1/81 DAILY COST ACC COST: AFE AMT: ETD 1286'/248' 20" D. 85' 68 PCF '174 SEC $ 47,351 $ 647,Z21 $2,81 3,000 2O58'/772' 20" D. 85' 68 PCF 130 SEC $ 29,066 $ 676,287 $2,813,000 2219'/161' 20" D. 85' 67 PCF 122 SEC $ 26,847 $ 703,134 $ 2,813,000 2730'/511' 20" D. 85' 67 PCF l l0 SEC $ 47,025 $ 750,159 $ 2,813,000 2730'/0' 20" D. 85' 68 PCF 210 SEC $ 43,883 $ 794,042 $ 2,813,000 2730'/0' 2O" D. 85' 68 PCF 190 SEC $ 38,921 $ 832,963 $2,813,000 DETAILS OF OPEP~ATI_OIIS, DESCRIPTIO[!S & RESULTS Dyna-drilled 12 1/4" hole f/ 1038' to 1280'. RD SDC. POOH. RIH w/ bit #3 on BHA #3 (60' belly). Reamed D/D run f./ lO00' to 1280'. Uirectionally dri'Yled 12 1/4" hole f/ 1280' to 1286'. NOW: Drlg @ 1286'. Directionally drilled 12 1/4" hole f/ 1286' to 1468'. POOH. RIH w/ bit #3 RR #1 on BHA #4 (90' belly). Directionally drilled 12 1/4" hole f/ 1468' to 2058'. POOH. RIH~w/ bit #4 on BHA #5 for ~na-drill Run #2. NOW: RIH w/ BHA #5. RIH w/ bit #4 on BHA #5 for Dyna-Drill Run #2. Tried to orient D/D - steering tool would not work. POOH w/ W. L. to check tools. POOH w/ d.p. to check orienting sub-ok. RIH w/ D/D. RIH w/ steering tool on GO W.L. - tools still would not work. (Lost 14 hrs. on W.L. failures). Oriented dyna-drill 700 rt. of high side w/ single shot surveys. Dyna-drilled 12 1/4" hole F/ 2058' to 2219'. POOH w/ D/D. RIH w/ bit #5 on BHA #6 (30' belly) for follow-up run. Reamed dyna-drill run F/ 2058' to 2219'. Directionally drilled 12 1/4" hole F/ 2219' to 2284'. Ran survey and POOH. RIH w/ bit #5 RR#1 on BHA #7 (locked-up assembly) and directionally drilled 12 1/4" hole F/ 2284' to 2730'. CIRC. and add 1 ppB of fresh gel to mud. POOH. R.U. Schlumberger. Ran Dil-Sonic-GR log. R.D. Schlumberger RIH w/ HO #1 on BHA #8 and opened 12 1/4" hole to 17 1/2" F/85' to 2120'. NOW: Opening hole @2120'. Opened 12 1/4" hole to 17 1/2" F/ 2120' to 2716'. CIRC. and POOH. RIH W/ 17 1/2" bit for wiper run. Had a few tight spots on trip in. Cleaned out to 2730'. CIRC and POOH. R.U. and ran 13 3/8" 61# K-55 buttress casing to 2695'. Landed casing on flow-thru hanger in 20'" casing head. NOW: RIH W/ 5" D.P. LEASE FEE LEASE - FREDRICKSON ·. , DATE 8 6i2/81 DA I LY COST' ACC COST: AFE ART: 9 6/3/81 DAILY COST' ACC COST' AFE AMT' 10 674/81 DAILY COST- ACC COST' AFE AMT' ETD 2730'/0' 2653' ETD (FC) 20" D. 85' 68 PCF 80 SEC $ 154,367 $ 987,330 $2,813,000 730'/0' 2653' ETD (FC) 20" D. 85' 68 PCF 43 SEC $ 27,102 $1,014,432 $2,813,000 2730'/0' 2705' ETD (Cmt) 2O" D. 85' 66 PCF 51 SEC $ 27,474' $1,041,906 $2,813,000 ¥;ELL I O, CLU #3 tlELD WILDCAT OF OPEFbA_TIO[IS~, I;:'ESCRIPTiOi,!S & .RESULTS. . Cut off 13 3/8" landing ~:t below rotary table. RIH w/ stab-in t%o1 on 5" DP. Stabbed into FC @ 2653' and brok, circ. Circ & cond mud - lowered viscosity. Cemented 13 3/8" .csg w/ 20 bbls of water ahead of 1210 sx cl "G" w/ 2% CaC12 and 2 1/2;,, pre-hyd gel water until received cement returns to surface. Tailed in with 300 sx cl "G,, w/ 2% CaC12~. Disp w/ 5 bbls H20 and 32 bbiq. mud (leaving 10 bbls of cement in DP). CIP'~..~7-40 hrs. 6/2/81. Pulled 14 stds of DP Drained flow n~pple - stack did not drain. verter stack and cleaned out cement. Ins~a-lq-e~ and tested CIW 20" 2M X 13. 5/8" 5M "WF" csg spool. (Note- Could not install junk catcher ring). Began to install 13 5/8" 5M BOPE. NOW: Installing 13 5/8"'5M BOPE. Installed BOPE. Began to test BOPE @ 16:00 hrs. Lower pipe rams would not test. Changed out inserts. Tested all other equipment - ok. Tested acc unit - had break in acc line. Repaired line and refilled acc' unit.. Acc unit would not test up to specs - pressure was 1050 psi after activation. It is required to be 1200 psi. Checked bladders and bottles- bottles were low on pressure. Retested lower pipe rams - still would not test. NOW: Changing out pipe rams. Opened gates on lower rams - found the single gate had been installed upside down. Reinstalled single gate. correctly. Retested BOPE - ok. Witnessed & approved by Doug Amos - O&G Cons Comm. Installed Kelly Spinner. RIH w/ bit #5 RR #1 on BHA #10 - tagged cement bridge @ 320'. CO 3' bridge & RIH. Tagged top of cement @ 2624'. Tested csg to 2500 psi. Drilled out cement and FC @ 2658' DPM. Tested csg to 2500 psi - ok. Drilled cement f/ 2658' to 2690' & tested csg to 2500 psi' - ok. Drilled out shoe @ 2698' & CO to 2708'. Pressured up csg shoe to 100 psi - bled to 90 psi in 3 min. Pressured up to 200 psi - bled to 190 psi in 3 min. Pres- sured up to 300 psi - bled to 290 psi in 3 min. Pressured up to 400 psi - bled to 350 psi in 15 min. Pressured up to 450 psi - bled to 365 psi in 10 min. Pressured up to 475 psi - bled to 380 psi in 15 min. Pressured up to 450 psi - bled to 250 psi (85 PCF equivalent) in 60 min. NOW' Performing leak-off test. LEASE UNION OIL Ca';PA h' OF CALIFOP 'iIA ,ELL RECOPJD FEE LEASE - FREDRICKSON ~iELL NO, CLU #3 FIELD SHEET D PAGF ih, 4 WILDCAT DATE ll 6/5/81 DAILY COST: ACC COST: AFE AMT: 12 6/6/8l DAILY COST: ACC COST: AFE AMT: 13 6/7/81 DAILY COST: ACC COST: AFE AMT: 14 6/8/81 DA I LY COST: ACC COST: AFE AMT: · .' 1'5 6'/9 / 8 i DAILY COST: ACC COST: AFE AMT: ETD 3286'/556' 20" D. 85' 13 3/8" C. 2695' 66 PCF 45 SEC $ 32,429 $1,074,335 $2,813,000 3596'/310' 20" D. 85' 13 3/8" C. 2695' 67 PCF 48 SEC $ 31,504 $1,105,839 $2,813,000 3733'/137' 2O" D. 85' 13 3/8" C. 2695' 67 PCF 44 SEC $ 49,120 $1,154,959 $2,813,000 4679'/946' 20" D. 85' 13 3/8" C. 2695' 68 PCF 47 SEC $ 37,168 $1,192,127 $2,813,000 4810'/131' 20" D. 85' 13 3/8" C. 2695' 68 PCF 44 SEC $ 47,939 $ 1,240,066 $ 2,813,000 ._DETAILS OF OPERATIOIIS, DE. SCRIPTIOI.!S & RESULTS Completed leak-off test of 13 3/8" csg shoe; Cleaned out cmt to 2730'. POOH- laid down S-135 DP. RIH w/ bit #7 on BHA ~ll (60' belly) and directionally drilled 12 1/4" hole f/ 2730' to 3lO1'. Found drift angle too high (2 previous surveys misread)-o8 Fanned hole to drop'angle. Dropped of angle. Directionally drilled 12.1/4" hole f/ 3101 to 3286'. RIH w/ bit #8 on BHA #12 (locked up assembly) and directionally drilled 12 1/4', hole f/ 3286' to 3518' POOH. RIH w/ bit #9 on BHA #13 for Dy~a-drill Run #3. Had tight spot in trip-"in hole @. 3059' 6 had to rotate thru. Oriented dyna-drill 80 left of HS & dyna-drilled 12 1/4" hole f/ 3518' to 3596'. Dyna-drilled 12 1/4" hole f/ 3.596' to 3688'. Had excessive left hand turn. Oriented dyna-drill 80° rt. of HS & reamed 12 1/4" hole f/ 3633' to 3688'. Continued to dyna- drill 12 1/4" hole f/3688' to 3733'_ Ran survey & POOH w/ WL. POOH w/ Dyna-drill. RIH w/ 12 1/4" HO on BHA #14 (locked assembly). Reamed dyna-drill run f/ 3633' to 3733'. POOH w/ HO. NOW: POOH w/ HO. Finished POOH w/ BHA #14. RIH w/ bit #10 on BHA #15 (locked up assembly). Direc- t.ionally drilled 12 1/4" hole f/ 3733' to 4679'. Circ & POOH. RIH w/ bit #11 on BHA #16 for Dyna-drill run #4. NOW' RIH w/ BHA #16. RIH w/bit #11 on BHA #16 for Dyna-drill Run #4 Hit ledge @ 3050'. Rotated D/D 180° and RIH to 4679'. R.U.E.W.S. on Go W.L. Dropped jt. of d.p. on W.L. Rehead steering tool and RIH w/ W.L. Oriented D/D 80° rt. of H.S. Dyna drilled 12 1/4" hole F/4679' to 4749'. Made d.p. connection. Steering tool came unseated while re-orienting D/D. Driller left 4OM# on D/D while trying to re-seat tool. D.P. was stuck. POOH w/W.L. Laid down 1 jt. of d.p. Pulled 290M# on d.p. - pipe would not pull free. Put left hand torque into d.p. and hit jars - pipe pulled free. RIH w/W.L, and continued to dyna drill f/4749' to 4810'. Steering tool showed a course direction of N-72-W. POOH w/W.L. Circ. and POOH w/D/D. RIH w/bit #12 on BHA #17 (30' belly) for follow-up run. Had tight spot @ 3836' - worked thru ok. NOW: RIH w/follow assembly. OIL CO;PA D' OF G ,LIFORI,iIA ELL RECOP, D S :EET D PAGE i]C), ,--5 LEASE FEE LEASE - FREDRICKSON ),iELL I O, CLU FIELD WILDCAT DATE 16 6/10/81 DAILY COST ACC COST' AFE AMT' 17 6/1i/81 DAILY COST' ACC COST' AFE AMT' 18 6/12/81 DAILY COST: ACC COST' AFE AMT' 19. 6/13/81 DAILY COST: ACC COST: AFE AMT' 20 6/14/81. DAILY COST: ACC COST: AFE AMT' ETD 5246'/436' 20" D. 85' 13 3/8" C. 2695' 72 PCF 49 SEC $ 58,407 $ 1,298,473 $ 2,813,000 '5422'/176' 20" D. 85' 13 3/8" C. 2695' 72 PCF 51 SEC $ 35,284 $1,333,757 $2,813,000 5632'/210, 20" D. 85' 13 3/8"C. 2695 71 PCF 53 SEC $ 31,943 $1,365,700 $2,813,000 5632'/O' 20" D. 85' 13 3/8" C. 2695 72 PCF 50 SEC $ 34,713 $1,400,413 $2,813,000 6222'/590' 20" D. 85' 13 3/8" C. 2695 74 PCF 53 SEC $ 32,615 $1,433,O28 $2,813,000 DETAILS_OF OPER/~TIDIIS, DESCRIPTIO.~.!S ~ RESULTS Finished RIH W/ follow assembly. Directionally Drilled 12 1/4" hole F/ 4810' to 4885'. CIRC. POOH. RIH W/ Bit #12 RR #1 on BHA #18 (Locked up assembly) and directionally drilled 12 1/4" hole F/ 4885' to 5246'. The hole drag increased 'substantially and the D.P. was stuck while drilling @ 5246'. Worked D.P. and hit. jars - D.'P. pulled fr.ee CIRC. and POOH - trip out was extremely rough. RIH W/ 12 1/4" H.O. #2 .RR #1 on'BHA #19 (Locked up assembly) to ream existing hOle.. Stopped @ shOe of 13 3/8" casing @ 2695' and CIRC. and condition mud. NOW: Condition mud and .raise weight. Continued to circ & cond mud @ 13 3/8" csg shoe. RIH - took weight @ 3616'. Reamed f/ 361 6' to 3706'. Continued to RIH - took weight @ 4685' Reamed hole f/ 4685' to 5246'. Circ ~lean. POOH - trip was smooth.' RIH w/ bit #13 on BHA #20 (locked up assembly). Trip was smooth. Directionally drilled 12 1/4" hole f/ 5246' to 5422'. NOW' Drlg @ 5422'. Directionally drilled 12 1/4" hole f/ 5422' to 5632'. While picking up for a connection the drive shaft from rig compound broke @ 02:30 hrs 6/12/81. Bit was 15' off bottom. Cannot operate drawworks or rotary table. Circ slowly and removed broken shaft. Wait on new shaft to be built. Received ne~ shaft and installed same @17-30 hrs 6/13/81. (Total down time - 39 hrs). Put 5 rounds of RH torque into DP & jarred down.~ Pipe came free in 20 min. POOH w/ DP - first 12 stands were ragged. Laid down "E" DP. Finished laying down "E" DP. RIH w/bit #14 on BHA #20. PU S-135 DP. Had tight spot @ 4800' - PU Kelly and~ rotated thru. Directional]y drilled 12 1/4" hole f/ 5632' to 5737'. Down 1 1/2 hrs due to bearing problem in compound. Bypassed bearing and directionally drilled 12 1/4" hole f/ 5737' to 6222'. NOW' Drlg @6222'. OIL CQ?A Y OF G LIFOPC-iIA ELL RECOP S ;EET D PAGE ih, -6 LEASE FEE LEASE - FREDRICKSON ~'-iELL [,I0, CLU #3 FIELD WILDCAT DATE 21 6/15/81 DAILY COST: ACC COST: AFE AMT: 22 6/16/81 DAILY COST: ACC COST: AFE AMT: 23 6/17/81 DAILY COST: ACC COST: AFE AMT: 24 6/18/81 DAILY COST: ACC COST: AFE AMT: 25 6/19/81 DAILY COST: ACC COST: AFE AMT: ETD 6297'/75' 20" D. 85' 13 3/8" C. 2695' 74 PCF 52 SEC $ 30,129 $1,463,157 $2,813,000 6914'/617' 20" D. 85' 13 3/8" C. 2695 74 PCF 52 SEC $, 34,679 $1,497,836 $2,813,000 7411'/497' 20" D. 85' 13 3/8" C. 2695' 74 PCF 51 SEC $ 39,854 $1,537,690 $2,813,000 7819'/408' 2O" D. 85; 13 3/8" C.'2695' 74 PCF 54 SEC $ 36,950 $1,574,640 $2,813,000 8054 '/235' 20' b. 85; 13 3/8" C. 2695' 73 PCF 49 SEC $ 37,056 $1,611,696 $2,813,000 OF OPERATIO[IS, DES.CRIPTIOI!S & RESULTS Directionally drilled 12 1/4" hole f/ 6222' to 6297'. Surveyed and POOH. Shut down to repair bearing in compound @ 06'30 hrs. Back in operation @.21.30 hrs (15 .hrs down). RIH w/ bit #15 on BHA #20. NOW: RIH w/ bit #15 on BHA #20. Completed~RIH w/ bit #15 on BHA #20. Directionally drilled 12 1/4" hole f/ 6297' to 6914'. Circ btms up for mud- loggers. POOH Hole was extremely tight for first 10 stands. Had to work thru spot @ 6824' Remainder of hole was smooth. Chan~ed bits. NOW' RIH w/ bit #16 on BHA #20. Completed RIH w/ bit #16 on BHA #20. Directionally drilled 12 1/4" hole f/ 6914' to 7200'. Ran survey - N.G. Directionally drilled 12 1/4" hole f/ 7200' to 7411' Circ & surveyed. POOH. Trip was fairl$ smooth. NOW: POOH w/ bit #16. SURVEY: 7369' 18 3/4° N72W BG - 80 units CG - 0 units Finished POOH. RIH w/ bit #17 on BHA #20. Trip was fairly smooth. Directionally drilled 12 1/4" hole f/ 7411' to 7717'. Ran survey. Directionally drilled 12 1/4" hole f/ 7717' to 7819'. NOW: Drlg @ 7819'. Surveys: 7676' 17 l/2° N71W 7679' -17 1/4° N71W BG 70 units CG 0 units TG 120 units Directionally drilled 12 1/4" hole f/7819' to 7824'. Circ & trip for bit change. RIH w/ bit #18 on BHA #20. Directionally drilled 12 1/4" hole f/ 7824' to 8054'. LEASE _ OIL EIF G LIFOP iIA ELL RECORD FEE LEASE - F.F~EDRICKSON !.,iELL l,lO, CLU #3 FIELD WILDCAT S :EE[ D PAGE ih, ..7 DATE 26 6/20/81 DAILY COST: ACC COST: AFE AMT- 27 6/21/81 DAILY COST' ACC COST' AFE AMT- 28 6/22/81 DAILY COST' ACC COST' AFE AMT' 29 6/23/81 8050' ETD DAILY COST' ACC COST' AFE AMT' ETD 8130'/?6' 20 D. 85; 13 3/8"'C. 2695' 73 PCF 49 SEC $ 31,228 $1,642,924 $2,813,000 8130'/0 20" D. 85; 13 3/8" C. 2695'~ 73 PCF 49 SEC $ 28,791 $1,671,715 $2,813,000 8130'/0' 20" D. 85' 18 3/8" C. 2695' 73 PCF 48 SEC $ 113,903 $1,785,618 $2,813,000 8130' (FC) 13 3/8" C. 2695' 9 5/8" C. 8130' 73 PCF 54 SEC $ 301,263 $2,086,881 $2,813,000 DETAILS OF OPER~NTIOI!S, DESCRIP_TIOI-!S ~ ,,~ RESULTS. Continued to drill 12 1/4" hole f/ 8054' to 8130' Circ and made wiper trip to shoe o~ csg. Wait 1 hr and RIH - trip was smooth. Circ & POOH. RU Schlumberger and RIH w/ DIL - Sonic log. Ran DIL-Sonic & FDC-CNL-GR log. Hole is getting sticky. RIH w/ bit #18 on BHA #20 for wiper trip. Circ & cond mud. POOH w/ BHA #20 - trip was smooth. ~RIH w/ HDT-Dipmeter. NOW' Running HDT'Dipmeter SURVEY- 8080' 17 1/40 N70W -: · Ran HDT-Dipmeter. RIH w/ SWS gun. Shot 45 SWS - rec 45. RD Schlumberger. RIH w/ bit #18 RR #2 on BHA #20. Trip was smooth - no fill. Circ & cond mud. POOH. LD BHA~ Changed pipe rams. RU & ran .. 9 5/8" 47# N-80 buttress csg. NOW' Running 9 5/8" csg. Completed running 207 jts of 9 5/8" 47# N-80 Buttress csg. Landed shoe @ 8130', FC @ 8050'. RU cement head & circ capacity of csg. Attempted to move pipe while circ. Coul'd pull up but di£ficult going down. Set pipe on bottom to cement. Pumped 20 bbls of BJ mud sweep. Cemented w/ 750 sx cl "G" w/ 2 1/2% prehyd gel, 3% KCL, .2% R-5, and .1% D-6 (to a weight of 97 PCF) followed by 1255 sxs cl "G" w/ 5% KCL, 1.7% D-29, .5% D-19, .5% D-31, 1% R-5, and .2% D-6 (to a weight of 119 PCF). The initial gel slurry was inconsistent due to settling in the prehyd tank. Displaced the cement w/ 10 bbls of H20 and 584 bbls mud to bump plug on FC @ 8050'. Bled off pres- sure - fl oats held ok Received +10 bbls of cement returns to surface. CIP @ 14'40 hrs 6/23/81. Cleaned out BOP stack. Lifted stack & set 9 5/8" csg slips. Cut off 9 5/8" landing joint. Installed CIW 13 5/8" 5M X 10" 5M "DCB" spool. NOW' Installing "DCB" spool. U['IIOH OIL CO ' PA Y ¢ QqLIFORHIA St ; L-T D PAGE ih, --8 ELL RECORD LEASE FEE LEASE - FREDRICKSON ViELL HO, CLU #3 FIELD WILDCAT DATE 30 6/24/81 DAILY COST: ACC COST: AFE AMT: 31 6/25/81 DAILY COST: ACC COST: AFE AMT: 32 6/26/81 DAILY COST: ACC COST: AFE AMT: 33 6/27/81 DAILY COST: ACC COST: AFE AMT: 34 6/28/81 DAILY COST: ACC COST: AFE AMT: 35 6/29/81 DAILY COST: ACC COST: AFE AMT: ETD 8130' 8110' ETD (Cmt) 13 3/8" C. 2695' 9 5/8" C. 8130' 74 PCF 58 SEC $ 105,377 $2,192,258 $2,81 3,000 8140'/10' 13 3/8" C. 2695' 9 5/8" C. 8130' 74 PCF 58 SEC $ 44,129 $2,236,387 $2,813,000 8514'/374' 13 3/8" C. 2695' 9 5/8" C. 8130' 74 PCF 52 SEC $ 46,796 $2,283,183 $2,813,000 8796'/282' 13 3/8" C. 2695' 9 5/8" C. 8130' 74 PCF 53 SEC' $ 32,360 $2,315,543 $2,81 3,000 9085'/289' 13 3/'8" C. 2695' 9 5/8" C. 8130' 78 PCF 55 SEC $ 44,537 $2,360,080 $2,813,000 9267'/182' 13 3/8" C. 2695' 9 5/8" C. 8130' 80 PCF 55 SEC $ 36,304 $2,396,384 $2,813,000' DETAIL OF OPEP~TIOIIS, DE. SCRIP. TIqI.!S & RESULTS Instal]ed & tested "DCB" spool & BOPE. RIH.w/ bit #19 on BHA #21. Tagged cmt @ 8041', tested 9 5/8" csg to 5000 psi. Drilled out float collar @ 8050' & cement to 8110'. NOW: Drilling out cement @ 8110'. Drilled oUt cmt to 8120' & tested 9 5/8" csg to 5000 psi. Drilled out cmt to · 8130' & shoe @ 8130' & new hole to 8140'. Tested 9 5/8" shoe to 94 PCF equiv for 40 min - no leak off. Circ & cond mud. POOH. Ran SDC gyro on GO WL f/ surface to 7670'. Could not work gyro below 7670'. POOH. Found gyro tool fouled w/ 'rubbers f/ cmt plugs.. NOW' RIH w/ bit #20 on BHA #22. RIH w/ bit #20 on BHA #22. Direction- ally drilled 8 1/2" hole f/ 8140' to 8514'. POOH for BHA change. r, 23. Direction- RIH w/ bit #21 on BHA ~ ally drilled 8 1/2" hole f/ 8514' to 8695'. POOH for BHA change. RIH w/bit #22 on BHA #24. Directionally drilled 8 1/2" hole f/8695' to 8796'. Directionally drilled 8 1/2" hole f/ 8796' to 9025'. Had drilling break @ ., 9025' & gas cut mud to surface. Circ , & conditioned mud to 78 PCF. Direction- ally drilled to 9085'. POOH for bit '~ change. NOW- RIH w/ bit #23 on BHA r, 25. RIH w/ bit #23 on BHA #25. Directionally drilled 8 1/2" hole f/ 9085' to 9267'. Increased MW to 80 PCF due to trip gas. Circ up break for mud loggers. POOH. NOW: RIH w/ bit #24 on BHA #26. LEASE U[';IOil OIL CO ?A h' CALIFOR iIA FEE LEASE - FREDRICKSON DATE ETD S :EET D PAGE ih, ---9 RECOPJD 36 6/30/81 .UELL CLU #3 FIELD WILDCAT DAILY COST: ACC COST: AFE AMT: 37 7/1/81 DAILY COST: ACC COST: AFE AMT: 38 7/2/81 DAILY COST: ACC COST: AFE AMT: 39 7/3/81 DAILY COST: ACC COST: AFE AMT: 40 7/4/81 DAILY COST: ACC COST: AFE AMT: 41 7/5/81 DAILY COST: ACC COST: AFE AMT: 9473'/206' 13 3/8" C. 2695' 9 5/8" C. 8130' 83 PCF 54 SEC $ 52,51 2 $2,448,896 $2,813,000 9741 '/268' 13 3/8" C. 2695' 9 5/8" C. 8130' 83 PCF 57 SEC $ 47,166 $2,486 ,O62 $2,813,000 9974'/233' 13 3/8" C. 2695' 9 5/8" C. 8130' 83 PCF 52 SEC $ 48,1 O0 $2,544,162 $2,813,000 10,108'/134' 13 3/8" C. 2695' 9 5/8" C. 8130' 85 PCF 53 SEC $ 49,795 $2,593,957 $2,813,000 10,214'/106' 13 3/8" C. 2695' 9 5/8" C. 8130' 84 PCF 58 SEC $ 30,583 $2,627,320 $2,813,000 10,411 '/197' 13 3/8" C. 2695' 9 5/8" C. 8130' 84 PCF 49 SEC $ 43,902 $2,671,222 $2,813,000 DETAILS OF OPEP, ATI.OIIS~ DESCRIPTIOI!S & RE, SULTS RIH w/-bit #24 on BHA #26. Directionally drilled 8 1/2" hole f/ 9267' to 9431'. Raised MW to 83 PCF. POOH. RIH w/ bit #25 on BHA #26. Directional ly drilled 8 1/2" hole f/ 9431' to 9473'. NOW: Drilling @ 9473' Directionally drilled 8 1/2" hole f/ 9473' tb 9710'. Short trip to shoe. Directionally drilled 8 1/2" hole f/ 9710' to 9741'. NOW: Drilling @ 9741'. Directionally drilled 8 1/2" hole f/9741' to 9974'. Directionally drilled 8 1/2" hole f/ 9974' to 9988'. POOH. RIH w/ bit #26 on BHA #26. Directionally drilled 8 1/2" hole f/9988' to 10108' looking for core pt. Directionally drilled 8 1/2" hole f/ lOl08', to lO160' looking for core pt. POOH. RIH w/bit #27 on BHA #27. Directionally drilled 8 1/2" hole f/ 10160' to 10,214'. Directionally drilled 8 1/2" hole f/ 10,214' to 10,394'. Drop survey. Short trip to shoe & rec survey. RIH & directionally drilled 8 1/2" hole .f/ 10394' to 10411'. NOW: Drilling @ lO411'. UNION GIL OF GqLIFOP -:IA S ;EET D PAGE ih, --.10 ELL RECORD LEASE FEE LEASE - FREDRICKSON ¥iELL !'lO, CLU #3 FIELD WILDCAT DATE 42 7/6/81 DAILY COST: ACC COST: AFE AMT:' 43 7/7/81 DAILY COST: ACC COST: AFE AMT' 44 7/8/81 DAILY COST: ACC COST: AFE AMT: 45 7/9/81 DAILY COST: ACC COST: AFE AMT: 46 7/10/81 DAILY COST: ACC COST: AFE AMT: 47'7/11/81 DAILY COST: ACC COST: AFE AMT: ETD 10545'/134' 13 3/8" C. 2695' 9 5/8" C. 8130' 84 PCF 53 SEC $ 47,898 $2,719,120 $2,813,000 10575'/30' 13 3/8" C. 2695' 9 5/8" C. 8130" 84 PCF 56 SEC $ 36,129 $2,754,249 $2,813,000 10696'/121' 13 3/8" C. 2695' 9 5/8" C. 8130' 85 PCF 56 SEC $ 36,418 $2,790,667 $2,813,000 0900' / 204' 13 3/8" C. 2695' 9 5/8" C. 8130' 84 PCF 54 SEC $ 34,355 $2,825,022 $2,81 3,000 lO,900'/0' 13 3/8" C. 2695' 9 5/8" C. 8130' 85 PCF 59 SEC $ 54,132 $2,879,154 $2,813,000 ll ,028'/128' 13 3/8" C. 2695' 9 5/8" C. 8130' 86 PCF 58 SEC $ 38,818 $2,917,972 $2,813,000 DE. TAIL, S OF .OPERL~TIOI~S, DESCRIPTIOI!S .,S._RE. SULTS Directionally drilled 8 1/2" hole f/ 10411' to 10545'. Looking for core pt. (Circ up samples @ 10505', 10515' & 10545'). ~ NOW: Trip' for core bbl. POOH. Picked up core bbl.' RIH w/ core bbl on BHA #28. Worked last 70' to btm. Cored f/ 10545' to 10575'. POOH. Layed down core - 100% recovery. Tested BOPE. NOW: RIH. RIH w/ bit #29 on BHA #30. Reamed 80' to btm. Directionally drilled 8 1/2" hole f/ 10575' to 10696' (looking for core pt). NOW: Drilling @ 10696'. Directionally drilled 8 1/2" hole f/ 10696' to 10900' TD. Circ clean. NOW: Survey. Surveyed & pulled to shoe. Wait @ shoe 2 hrs. RIH. Hit bridge on trip in @ 3 2/3 stds off btm. Reamed to btm. Circ & icond hole for logs. POOH Ran Schlumberger DIL-Sonic w/ SP & GR. Log stopped @10680'. Logged f/10680' to 9 5/8" shoe. Rigged down Schlumber- ger. RIH w/ bit #30 on BHA #'30. Reamed to btm f/ 10696' to 10900'. Directionally drilled 8 1/2" hole f/lO900' to'11,028' LEASE UNION OIL· CALIFOP .iIA ELL RECOP FEE LEASE - FREDRICKSON .,;ELL NO, CLU #3 FIELD WILDCAT S ;EET D PAGE ih, --- 11 DATE 48 7/12/81 DAILY COST: ACC COST: AFE AMT: 49 7/13/81 DAILY COST: ACC COST: AFE AMT: 5(9 7/14/81 DAILY COST: ACC COST: AFE AMT: 51 7/15/81 DAILY COST: ACC COST: AFE AMT: 52 7/16/81 DAILY COST: ACC COST: AFE AMT: ETD 11,125'/97' 13 3/8" C. 2695' 9 5/8" C. 8130' 87 PCF 58 SEC $ 31,159 $2,949,131 $2,813,000 11125' TD 13 3/8" C. 2695' 9 5/8" C. 8130' 87 PCF 58 SEC $ 29,274 $2,978,405 $2,813,000 11125' TD 13 3/8" C. 2695' 9 5/8" C. 8130' 87 PCF 58 SEC $ 144,092 $3,122,497 $2,813,000 11125' TD 13 3/8" C. 2695' 9 5/8" C. 8130' 87 PCF 61 SEC $ 90,064 $3,212,561 $2,813,000 11125' TD 13 3/8" C. 2695' 9 5/8" C. 8130' 87 PCF 50 SEC $ 28,828 $3,241,389 $2,813,000 DETAILS OF OPERATi_OIIS, DESCRJPTIOI.!S & RESULTS Directionally drilled 8 1/2" hole f/ 11,028' to 11,125'. Circ clean. Pulled to shoe. Waited 2 hrs. 'Run to btm. Had to ream f/ 10691 to 10816' & had 30' fill-on btm. Circ & cond mud for logs & raised wt to 87 PCF. NOW: 'Cond mud & hole for logs. Finished conditioning mud and hole for logs. ·'POOH (trip out was good). Rigged up.Schlumberger. Ran DIL/ Sonic/SP/GR and FDC/CNL logs. Ran di pmeter. NOW: RIH w/ SWS gun. RIH w/ SWS gun, Shot 45 SWS,. rec 36. Did not lose any bullets in hole. RD Schlumberger. RU GO WL, RIH w/ VDL/GR log. Log stopped @ 9370'. Ran log f/ 9370' to 7600'. RD GO WL. RIH with bit #30 on BHA #30 for CO run. Trip in was good. Circ & cond hole for logs. POOH. RU Schlumberger. Reran FDC/CNL/GR log (original log was defective). NOW: Running FDC/CNL/GR log. Ran FDC/CNL/GR log. RD Schlumberger. RU GO WL. Ran~IbL/GR log f/ llllO' to 7600'. RD GO WL. RIH w/ bit #30 on- BHA #30 for CO run. Had 3' of fill. Circ and cond mud.. Made short trip to csg shoe - had some tight hole. RIH & circ & cond mud. NOW: POOH to run 7" liner. Finish'ed pOOH;~w/ DP. RU to run 7" liner. Changed rams in BOPE. Ran 80 jts of 7" 29# N-80 Buttress csg on 5" DP. (Note: Found x-over on top of liner hanger cut incorrectly - down +2 hrs waiting on new x-over). Lande~ shoe @ 11086' (39' high), float collar @ 11046', junk catcher @ 11003', landing.collar @ 10959', BOT hanger @ 7787', and top of tie-back sleeve @ 7743'. Broke circ & attempted to wash liner to bottom - could not. Circ and cond mud prior to cementing. NOW: Circ and cond mud. LFZ SE FEE LEASE - FREDRICKSON DATE ETD UNION OIL Ca';P/ N · G LIFOI '-iIA PAGE ih, --12 RECORD 53 7/17/81 !..iELL NO, CLU FIELD WILDCAT DAILY COST: ACC COST: AFE AMT: 54 7/18/81 DAILY COST: ACC COST: AFE AMT: 55 7/19/81 DAILY COST: ACC COST: AFE AMT: 56 7/20/81 · . DAILY COST: ACC COST: AFE AMT: 57 7/2]/81 DAILY COST: ACC COST: AFE AMT: 11125' TD 9 5/8" C. 8130' 7" L. 11125' to 7783' 86 PCF 48 SEC $ 63,503 $3,304,897 $2,813,000 11125' TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 11125' to 7783' 85 PCF 51 SEC $ 29,077 $3,333,967 $2,813,000 11125' TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 11125' to 7783' 86 PCF 52 SEC $ 24,880 $3,358,849 $2,813,000 11125' TD 10998' ETD (LC) 9 5/8" C. 81 30' 7" L. 11125' to 84 PCF 55 SEC $ 53,175 $3,412,024 $2,813,000 11,1 25' TD 9922' ETD (RET) 9 5/8" c. 8130' 7" L. 11125' to 7783' 80 PCF 40 SEC $ 55,763 $3,467,787 $2,813,000 DETA I .LS OF .OPERAT I OI IS ~ DESCR l p.T I OI!S .,S .RESULTS. Circ & cond mud. Set liner hanger w/ 2200 psi. Put 30 bbls of ~ mud sweep ahead of 1000 sxs c l "G" w/ 1.7% D-29, .5% D-19, .5% D-31, .2% R-5, .2% D-6, and 5% KCL. Had good circ throughout job. Displaced plug w/ 4 bbls H20 and 248 bbls mud. Bumped plug w/ 2000 psi. CIP @ 10:30 hrs 7/17/8l. Floats held ok. POOH w/ DP. Laid down HWDP. RIH w/ bit #31 and' csg scraper on BHA #31 to 6150'. Circ and WOC. NOW: WOC. WOC. RIH~& tagged top of liner @ 7783' (had error in previously reported liner depth- float shoe actually on bottom @ 11125'). Had no cement on top of liner. Pressure tested liner lap to 2400 psi for 15 min'- ok. Circ & POOH. RIH w/ 6" bit & 7" csg scraper on 4 3/4" DC's and RIH ':~w/ 3510' of 3 1/2" DP & remainder of 5" DP. Tagged landing collar @.10998' - had no cement inside liner. Circ btms up & pressure tested csg and liner lap to 5000 psi for 15 min - ok. NOW: POOH w/ DP. POOH w/ DP. RIH w/ 9 5/8" Howco RTTS w/ auxiliary valve on dry DP & set tool @ 7699'. Opened tool w/ weak blow. Had tool open 1 hr. Test was dry. POOH w/ tools. RU GO WL. Ran CBL-CCL-Neut-GR log f/ 10983' to~2600'. Now running VDL log. NOW: Running VDL log. Ran VDL/GR log f/ 10983' to 7600'. Ran SDC gyro survey f/ 10980' to 7100'. Set 5" DP to one side and PU 3 1/2" DP. 7783' NOW: PU 3 1/2".DP. Finished PU 3 1/2" DP. Circ & POOH. RU GO WL & perfed 4-1/2" HPF f/ 9936' to 9938' DIL for BS #1. Ran CCL log for tie-in and set cmt ret @ 9922' DIL on WL. Ran gauge ring and junk basket. RD GO WL. RIH w/ stab-in tool on 3 1/2" DP. Broke circ at top of ret. Stabbed into ret @ 9929' DPbl. Broke down for- mation w/ 2200 psi. Pumped in w/ 1.5 BPM @ 2400 psi. NOW' Prep to squeeze for BS #1. DATE UHIOrl OIL CgPA N OF CALIFOP qlA FEE LEASE - FREDRICKSON SI-;EET D PAGE --' 13 k. ELL RECOPJD 58 7/22/81 I-.;ELL CLU #3 FIELD WILDCAT DAILY COST' (Includes 7" ACC COST' AFE AMT' 59 7/23/81 DAILY COST' ACC COST' AFE AMT' ETD 11125' TD 9850' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 84 PCF 48 SEC $ 132,509 Liner) $3,6OO,396 $2,813,000 11125' TD 9388' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 81 PCF 37 SEC $ 44,046 $3,664,342 $2,813,000 DETAI.L,S OF O,PERATiOflS, DESCRIPTIO_~.!S o _,_~ RESULTS. Mixed & sqz'd BS #1 perfs f/ 9936' to 9938' DIL w/ 100 sxs CL "G" w/ 40 gal/lO0 sxs D-45L, 4 gal/lO0 sxs R-12L, and 1 gal/lO0 sxs D-6L. Had final rate of 5 CFM'@ 2450 psi. Held 2000 psi w/ pumps off 5 min. Pulled out of ret & rev out O' sxs cmt. CIP @ 02:00 hrs 7/22/81. POOH w/ 3 1/2" DP. WOC for 12 hrs. RIH w/ GO. WL & perfed 4-1/2" HPF f/ 9898' to 9900' DIL for BS #2. POOH w/ WL. RIH w/.-7" Howco cmt ret on 3 1/2" DP & set ret @ 9850' DIL (9865' DPM). Tested surface equip to 6000 psi & csg to 5000 psi.. Broke down perfs w/ 2800 psi. Pumped into perfs w/ 3 BPM ca 3000 psi. Form held 2000 psi w/ pumps off 3 min. Mixed and squeezed w/' 200 sxs CL "G" w/ 40 gal/lO0 sxs D-45L,'4 gal/lO0 sxs R-12L, 1 gal/lO0 sxs D-6L and 50 sxs CL "G" w/ 8 gal/lO0 sxs R-12L, 1 gal/lO0 sxs D-6L. Displaced 226 sxs behind perfs. Had final rate of 7 CFM @ 2400 psi. Sqz held 2000 psi w/ pumps off 5 min. CIP ca 20:50 hrs 7/22/81, Picked up out of ret & rev out 15 sxs cmt. POOH w/ 3 1/2" DP. NOW' POOH w/ 3 1/2" DP. Completed POOH w/ 3 1/2" DP. RU GO WL & perfed 4-1/2" HPF f/ 9408' to 9410' DIL for BS #3. RIH & set 7" Howco cmt ret @ 9388' DIL on WL. RD GO WL. RIH w/ stab-in tool on 3 1/2" DP & stabbed into ret ca 9388' DIL. Tested surface equip to 6000 psi & csg to 5000 psi. Broke down perfs w/ 2900 psi. Pumped into perfs w/ 2 BPM ca 2750 psi. Formation held 2000 psi w/ pumps off 2 min. ' Mixed & sqz'~d BS #3 w/ 150 sxs CL "G" w/ 40 gal/lO0 sxs D-45L, 4 gal/lO0 sxs R-12L, 1 gal/lO0 sxs D-6L & 100 sxs CL "G" w/ 6 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L. Displaced 226 sxs behind perfs w/ a final rate of .75 BPM @ 2900 psi. Sqz held 2500 psi w/ pumps off;.5 min. CIP @ 10'50 hrs. Rev out 20 sxs cmt. POOH w/ DP. WOC 12 hrs. RU GO WL & perfed 4-1/2" HPF f/ 9372' to 9374' DIL for BS #4. NOW' POOH w/ WL. OIL CO ;PA h' CF CALIFOP, qIA - £LL RECOPZ) S ;EET D PAGE ih, ---14 · LEASE FEE LEASE - FREDRICKSON I.iELL I O, CLU FIELD WILDCAT DATE 60 7/24/81 DAILY COST' ACC COST' AFE AMT' 61 7/25/81 DAILY COST' ACC COST' AFE AMT' 62 7/26/81 DAILY COST' ACC COST' AFE AMT' 63 7/27/81 DAILY COST' ACC COST' AFE AMT' ETD 1112,5' TD 9285 ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 46 SEC $ 52,119 $3,696,461 $2,813,000 11125' TD 9275' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 46SEC $ ~8,333 $3,734,794 $2,813,000 11125' TD 9865' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 82 PCF 46 SEC $ 26,958 $3,761,752 $2,81 3,000 11125' TD 10998' ETD (LC) 9 5/8" c. 813o' 7" L. 11125' to 7783' 83 PCF 51 SEC $ 32,918 $3,794,670 $2,813,000 OF OPERATIO[IS, DESCRIPTIOf.!S ~ RE. SULT. S POOH w/ WL. RIH w/ 7" cmt ret on 3 1/2" DP & set ret @ 9285' DPM (9270' DIL). Tested surface equip to 6000 psi & csg to 5000 psi. Broke down perfs f/ 9372.' to 9374' DIL w/ 2600 psi. Pumped in w/ 2 BPM @ 3000 psi. Formation 'held 2000 psi w/ pumps off 2 min. Mixed & sqz'd BS #4 perfs w/ 150 sxs CL "G" w/ 40 gal/lO0 sxs D-45L, 4 gal/lO0 sxs R-12L, 1 gal/lO0 sxs D-6L and 150 sxs CL "G" w/ · 6 gal/lO0 sxs R-12L, 1 gal/lO0' sxs D-6L. DisPlaced-212 sxs behind perfs w/ a final rate of 1 BPM @ 3800 psi. Sqz held 3100 psi w/ pumps off 5 min. CIP @ 05:25 hrs 7/24/81. Rev out 69sxs of cmt. POOH w/ DP. RIH w/ 6" bit on. 4 3/4" DC's to liner top @ 7783'. WOC 12 hrs. RIH & tagged ret @ 9285'. Drilled on ret, NOW' Drilling on ret @ 9285'. Drilled out ret @ 9285' & firm cmt down to ret @ 9388'. Attempted to test BS #4 holes f/ 9372' to 9374' DIL w/ 2500 psi - holes took fluid. Pressure bled to 2100 psi in 10 min. Pumped into formation w/ 2 BPM @ 3200 psi. POOH w/ 3 1/2" DP. RIH w/ 7" cmt ret on 3 1/2" DP & set ret @ 9275' DPM (9260' DIL). Mixed & sqz'd BS #4 Stage #2 w/ 150 sxs CL "G" w/ 40 gal/lO0 sxs D-45L, 6 gal/lO0 sxs R-12L, 1 gal/lO0 sxs D-6L & 100 sxs CL "G" w/ 6 gal/lO0 sxs R-12L, 1 gal/lO0 sxs D-6L. Displaced 220 sxs behind perfs w/ a final rate of .75 BPM @ 3750 psi. Sqz held 3150 psi w/ pumps off 5 min. CIP @ 16:45 hrs 7/25/81. Rev out 10 sxs cmt. POOH w/ 3 1/2" DP. RIH w/ 6" bit on 12-4 3/4" DC's & 10 its of 3 1/2" HWDP to liner top @ 7783'. WOC. NOW' WOC 12 hrs. WOC 12 hrs. RIH w/ 6" bit & tagged ret @ 9275'. Drilled out ret & firm cmt to 9398' Pressure tested BS #4.Stage #2 f/ 93?2' to 9374' DIL. Holes took fluid @ 1/4 BPM @ :2500 psi. Bled to 2250 psi in 5 min. Drilled ret @ 9398' & firm cmt to 9428'. CO cmt stringers to 9525'. POOH for bit change. NOW' RIH w/ new 6" bit. RIH w/ 6" bit on 4 3/4" DC's. Drilled ret @ 9865'. Cleaned out firm cmt to 9932'. Drilled ret @ 9932'. Cleaned out cmt to 9938' RIH & tagged LC @ 10998'. Circ & ~OOH. RIH w/ 7" csg scrpr on 6" bit to 10998' ETD. Circ & POOH. NOW: POOH w/ csg scraper. OIL CC ' ?A IY OF CALIFOR qIA · WELL RECOP S ;EET D PAGE i-lO, ---I 5 'J_ASE FEE LEASE - FREDRICKSON I., ELL [;0, CLU FIELD WILDCAT DAlE 64 7/28/81 DAILY COST: ACC COST' AFE AMT' 65 7/29/81 DAILY COST' ACC COST' AFE AMT' 66 7/30/81 DAILY COST' ACC COST' AFE AMT' ETD 11125' TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 1..1125' to 7783' 83 PCF 50 SEC $ 26,610 $3,821,280 $2,813,000 11125' TD 10998' ETD (LC) 9 5/8" c. 8130' 7" L. 11125' to 7783' 83 PCF 50 SEC $ 30,468 $3,851,748 $2,813,000 11125' TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 52 SEC $ 37,252 $3,889,00o $2,81 3,000 DETAILS OF OPERATIOIIS, DESCRIpTIq.!S & RESULTS Finished POOH w/ bit & scrpr. RIH w/ Howco. RTTS pkr & hydrO-spring tester on dry DP to dry test squeezes. Set dowp on liner top & hydro-spring failed o_pea. POOH w/ DP. RIH w/ RTTS pkr & APR valve & set pkr @ 9336'. Tested test head to 6000 psi - would not test. Replaced head. Tested new head to 6000 psi ' ok. Opened APR valve & drY tested 4 squeezes. Had increasing blow for 20 min, Closed APR valve. RIH w/ DP & reset RTTS @ 9825' to test squeezes #1 & #2. Opened valve & had slight blow for 40 min (Note' annulus bled from 2300 psi.-to 1750 psi). Closed APR valve & attempted to RIH w/ test tools. Pkr would not go' dOwn hole. POOH w/ tools. NOW' POOH w/ dry test tools. POOH w/ test tools. RIH w/ 6" bit & casing scraper to 10998'. Circ btms up. POOH laying down 5" DP. RIH w/ DST tools (60' tbg tail, RTTS, bundle carrier, and auxiliary valve) w/ 2000' water cushion on 3 1/2" DP. Set RTTS pkr @ 10409'. Opened auxiliary valve. Installed 4' perf gun in lubricator & tested surface lines. NOW' Testing surface lines. Attempted to test manifold - master valve leaked. Changed out o-ring & retested - still leaked. Changed out manifolds - master valve tested but swivel leaked. Left master valve on & changed manifolds. Pressure tested to 6000 psi - ok. Tested lubricator to 6000 psi & lines to 5000 psi. RIH w/ 4' of 4-1/2" HPF link-jet perf gun w/ 0° phasing - gun stopped @ 9420'. POOH w/ WL. .RIH w/ 2 1/8" sinker bars & jars - stopped @ 9420'. Attempted to jar thru obst~ruction - could not. POOH w/ WL. RIH w/ 1 11/16" sinker bars & jars - stopped @ 9420'. POOH w/ WL. Released RTTS to reverse out. Drill pipe plugged after started reversing. Attempted to pump down DP - pressured up to 2500 psi & held. POOH w/ DP. Pulled 13 stands of wet DP & found DP plugged with cement scale. Washed & rabbited DP. NOW' Washing & rabbiting DP on trip out. UNIO I OIL CO[PA h' CALIFOR 'iIA kECORD S ;EET D PAGE ih, ---16 LEASE ..... FFF [FASF..- FREDRICKSON .,iELL NO, CLU FIELD WILDCAT DATE ETD 67 7/31/81 DAILY COST: ACC COST: AFE AMT: 68 8/1/81 DAILY COST: ACC COST: AFE AMT: 69 8/2/81 DAILY COST: ACC COST: ' AFE AMT: 70 8/3/81 DAILY COST: ACC COST: AFE AMT: 11125' TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 49 SEC $ 36,716 $3,925,716 $2,81 3,000 11125' TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 48 SEC $ 32,391 $3,958,107 $2,813,000 11125' TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 51 SEC $ 27,673 $3,985,78O $2,813,000 11125' TD 10998.' ETD (LC) 9 5/8" C. 8130' 7" L. 7783' to 11125' 85 PCF 47 SEC $ 54,638 $4,040,418 $3,986,000 .,.DETAILS OF OP~ERATIOIISt DESCRIPTIO, I-!S & ,RESULTS POOH. Washed cmt scale & rabbited DP. RIH'w/ test assy w/ 2000' water cushioN. RU test head & lines & tested to 6000 psi. Set RTTS @ 10430', tail @~10497' DPM. RIH w/ 4' perf.gun - tail of test string de- termined to be too close to upper perfor- ations. POOH w/ perf gun. Released RTTS - hydrospring tester failed to close al- lowing mud to fill DP. Reverse circ DP & POOH~ Found cmt scale & nails in hydro- spring tester. Lost 2 rubber elements off of RTTS pkr. RIH w/ gauge ring & junk basket - stopped @ 10709'. Worked GR & JB down to 10717' - could not go deeper. POOH - had'rubber pcs in junk basket. RIH w/ new.test assy (60' .tubing tail, RTTS pkr, bundle carrier, APR valve, 1 std of 3 1/2" DP, and pump-out ~ub). Rabbited DP in hole. NOW: RIH w/ test assy. RIH w/ test assy whilerabbiting DP. Set RTTS @ 10387', tail @ 10454' DPM. Opened APR valve w/ 1900 psi. RU test manifold & lubricator & tested to 6000 psi. RIH w/ 4' perf gun - gun stopped @ 10350' WLM (9' above APR valve). Removed surface equip & POOH w/ DP - had 2OM# drag off btm. RIH w/ bit & csg scrpr to 10700'. Circ btms up. POOH w/ DP. NOW: POOH w/ bit & csg scrpr. POOH w/ DP. PU & RIH w/ new string 3 1/2" DP open ended. Circ w/ both pumps btms up. RU WL. Ran 2 3/8" GR thru DP. RD WL. POOH w/ DP. Make up 'test tools: 60' tbg tail, RTTS pkr, bundle carrier, APR valve, 1 std 3 1/2" DP, pump out sub on 3 1/2" DP. Strap in hole. NOW: Open APR valve & RIH w/ WL. Set RTTS @ 10391' DPM. Installed & tested lubricator to 6000 psi. Opened APR valve & RIH w/ 2 1/8" perf gun. Unable to work gun below 10356' CBL. RIH w/ 2 1/8" sinker bars - stopped @ 10356' CBL. RIH w/ 1 3/4" sinker bars- stopped @ 10356' CBL. POOH w/ test tools. Rabbited all tools on trip oUt - found nothing to indicate restriction in DP. Picked up new APR valve. RIH w/ test tools w/ 2000' mud cushion. Set RTTS @ 10415'. Installed & tested lubricator to 6000 psi. Opened APR valve & RIH w/ 2 1/8" perf gun. Unable to work thru APR valve @ 10390'. NOW: POOH w/ wireline. Ui'lIOll OIL CD?AIN OF CALIFORtlIA ELL RECORD S}:L- T D P^ E ih, LEASE FEE LEASE- FREDRICKSON 'ELL HO, #3 FIELD DATE 8/4/8' DAILY COST ACC COST' AFE AMT' 72 8/5/81 ETD 11125' TD 10998' ETD (LC) 9 5/8" C.'8130' 7" L. 11125' to 7783' 84 PCF 45 SEC $ 36,660 $4 ,O77,078 $2,813,000 ll125'-TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 11125' to 7783' 84 PCF 43 SEC DAILY COST: $ 24,852 ACC COST: $4,101,930 AFE AMT' 73 8/6/81 $2,813,000 lll25' TD 10998' ETD (LC) 9 5/8" c. 8]30' 7" L. '11125' top @ 7783' 84 PCF 44 SEC DAILY COST' $ 39,788' ACC COST' $4, !42,718 AFE AMT' $2,81 3,000 DETAIkS .OF OPEPATiO[tS, DESCRIPTIOI!S..i..2_,, RESUL.TS POOH W/ test tools. Layed down APR valve. J Function tested BOPE. RIH & set RTTS w/.aux valve @ 10400' w/ 2000' mud cushion. Tail @ 10465'. Installed & tested lubricator & test manifold to 6000 psi. 'Perfed 4 HPF w/ 2 1/8" guns f/ 10530' to 10534' @ 14:10 hrs. Slight blow for 1 hr. Perfed f/ 10516'. to 10534' @ 17:00 hrs. No entry. Perfed f/ 10504' 'to 10512' DIL @ 20:10 hrs - slight blow. Observed well until 22:00 hrs. No increase, only slight blow. Pul 1 ed RTTS 1 oose. NOW' Killing well. Circ clean after DST #1. POOH w/ test tools - had some drag in 7" liner. RIH w/ 6" bit on 7" csg scraper - had to rotate thru tight. spots @ 10548' & 10795'. Tagged LC @ 10998'. Circ hole clean - rec some rubber pcs & perf gun parts. POOH w/ DP. RIH w/ test tools (60' tbg tail, RTTS, bundle carrier, aux valve, and pump-out sub 1 std up. Set RTTS @ 10020' DPM, tail @ lO091' DPM. Tested surface equip to 6000 psi. Opened aux valve. NOW' Prep to reperf DST #lC. ~RIH w/ 8' perf gun on GO WL. Reperfed DST #lC f/ 10504' to 10512' DIL @ 03:32 i.hrs. Had slight blow for 1 1/2 hrs. Added 2000' water cushion to DP. RIH w/ 20' perf gun. Attempted to perf DST #2 f/ 10128' to 10148' DIL. Had a missfire. Left guide.spear from bottom of gun in hole. RIH w/ 20' perf gun - stopped @ 9603'. Worked gun down to 9688'. POOH w~ gun. RIH w/ 2 1/8" gauge cutter,,2 1/8" ~inker bars, and jars on WL. Pushed juhE out tubing tail @ 10091'. POOH w/ WL. RIH w/ 20' perf gun &.-perfed DST #2 f/ 10128' to 10148' DIL.. Had weak blow in bub-le bucket. RIH w/ 20' perf ~ gun'& reperfed DST #2 - had no improvement. POOH w/ WL. Shut well in 23:00 hrs for pressure buildup. NOW: Well shut in for~pressure buildup. uHI0rt OIL CgP/ N .OF CALIFOP 'iIA ELL RECORD S :EET D PAGE ih. LEASE FEE T,PASE - FREDRICKSON I I LL HO, c ,u FIELD DATE 74 8/7/81 DAILY COST: ACC COST: AFE AMT: 75 8/8/81 DA I LY COST: ACC COST: AFE AMT: 76 8/9/81 DAILY COST: ACC COST: AFE AMT: ETD 11125' TD 10998' ETD (LC) 9 5/8" C. 8130' 7" L. 11125', top @ 7783' 83 PCF 52 SEC $ 38,315 $4,18O, O33 $2,813,000 11125' TD 10020' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to' 7783' 83 PCF 54 SEC $ 42,761 $4,222,794 $2,813,000 11125' TD. 10020' ETD (RET) 9 5/8" C. 81 30' 7" L. 1t125' to 7783' 83 PCF 53 SEC $ 34,134 $4,256,928 $2,813,000 DETAILS OF .OPEP, ATiOIIS, DESCRIPT. IQI!S & RES.ULTS Well shut in for pressure buildup. Attempted to pull pkr loose - could not. Attempted to circ thru bypass - no good. Filled DP from the top - could not circ thru bypass. Pulled pkr loose. Broke circ. Attempted to reverse circ - could not. RIH w/ test tools -.could not work RTTS pkr below top of DST #2 perfs @ 10128' DIL.- 'Pulled.up 10' & circ & cond mud. POOH W/ test tools. RIH w/ 6" bit on 7" csg ~:scraper - tagged LC @ 10998,. Pulled up 1 std & circ clean. POOH. RIH w/ 7" cmt ret on 3 1/21' DP. 'NOW: RIH w/ 7" cmt ret.. RIH w/ 7" cmt ret. Set ret'-@ 10391'. Tested surf equip to 6000 psi & csg to 2500 psi. Broke down DST #1 perfs f/ 10504' to 10512' & 10516' to 10534' DIL w/ 3300 psi.. Pumped in w/ 2 BPM @ 3500 psi. Formation held 1400 psi w/ pumps off 5 min. Mixed 200 sxs cl "G" cmt w/ 8 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L to 119 PCF. Displaced 100 sxs below ret. Had final rate of .5 BPM @ 6000 psi. Sqz held 5500 psi after 5 min. CIP @ 06:45 hrs 8/8/81. Rev out 100 sxs cmt. POOH w/ DP. RIH w/ 7" cmt ret on 3 1/2" DP. Set ret @ 10020'. Tested surf equip to 6000 psi & csg to 2500 psi. Broke down DST #2 perfs f/ 10128' to 10148' DIL w/ 3500 psi. Pumped in w/ 3 BPM @ 3000 psi. Formation held 1500 psi w/ pumps off 1 min. Mixed 200 sxs cl "G" cmt w/ 8 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L. Displaced 185 sxs below ret w/ a final rate of 8 CFM @ 3250 psi. Sqz held 2000 psi w/ pumps off 5 min. CIP @ i6:50 hrs 8/8/81. Rev out 15 sxs cmt. POOH w/ DP. RIH w/ test tools on 3 1/2" DP. NOW: RIH w/ test tools. RIH w/ test to°l~ for DST #3 (60' tbg tail, RTTS pkr, bundle carrier, aux valve). Could not get RTTS pkr into 7" liner. POOH. Changed out RTTS. RIH w/'test tools & set pkr @ 9795', tail @ 9863' DPM. Opened aux valve & checked sqz perfs for entry - none. RIH w/ 13' perf gun & perfed DST #3 f/ 9902' to 9915' DIL. Had moderate blow in bubble bucket. Well appeared to die several times. Shut well in & attempted to POOH w/ WL tools. Tools stuck inoRTTS pkr. Had slight move- ment in tools but could not pull loose. Pumped 23 bbls of mud down DP (DP volume is 60 bbls) & WL tools pulled free. POOH w/ WL. RD GO WL. Finished filling DP w/ mud & pulled pkr loose. Rev out & rec large amts of sand when mud behind water cushion surfaced. Circ hole clean. NOW: Circ well. .. U 'IIOil OIL CCI?AIN CF CALIFORIiIA ELL RECORD PAGE -i,9 LEASE FEE LEASE - FREDR_ICKSON ~]LL NO, CLU #3 FIEI~ ~rr~ DATE 77 8/10/81 ETD 11125' TD 9775' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' '- 83 PCF 53 SEC DAILY COST: $ 33,946 ACC COST: $4,290,874 AFE AMT: 78 8/11/81 DAILY 'COST: ACC COST: AFE AMT: 79 8/12/81 $2,813,000 11125' TD 9775' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 55 SEC $ 29,924 $4,320,798 $2,813,000 11125' TD 9775' ETD'.(RET) 9 5/8" c. 8130' 7" L. 11125' to 7783' 83 PCF 50 SEC DAILY COST: $ 42,139 ACC COST: $4,362,937 AFE AMT: $2,813,000 OF Circ & cond mud. POOH w/ test tools. RIH w/ 7" cmt ret on 3 1/2" DP & set ret @ 9775'. Tested surf 'equip to 6000 psi, csg to 2500 psi. Pumped into DST #3 perfs f/ 9902' to 9915' DIL w/ 2 1/4 BPM @ 2500 psi.. Formation held 2000 psi w/~ pumps off. Mixed & squeezed w/ 200 sxs cl "G" w/ 8 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L. Displaced 189 sxs below ret w/ a final rate of 2 1/2 BPM @ 3200~psi. CIP @ 10:50 hrs 8/10/81. Rev out l l sxs cmt. POOH w/ DP. RIH w/ test tools (60' tbg tail, RTTS pkr, bundle carrier, full fl ow hydrospring tester-, pumpout sub). 'Discovered hydrospring was open w/ 5.stds in hole. POOH. LD hydrospring & RIH w/ APR valve. Could not get RTTS pkr thru liner top. POOH. NOW: Change out pkrs. Changed out RTTS pkrs. RIH w/ DST tools & set pkr @ 9275', tail @ 9347'. RU test manifold. Opened APR valve & tested BS holes for entry - ok. Tested lubricator & manifold to 6000 psi. RIH w/ 14' perf gun. Gun stopped at top of APR valve. Opened & closed APR valve several times - still could not get thru. POOH w/ gun. RIH w/ 2 1/8" gauge cutter, sinker bars, and jars on WL - could not. work thru APR valve. POOH w/ WL. Re- leased RTTS & POOH w/ test tools. Re- placed APR valve w/ aux valve. RIH w/ test tools & set pkr @ 9279', tail @ 9351'. Opened aux valve & tested lubricator & manifold to 6000 psi. RIH w/ 14' perf gun - stopped in aux valve. Gun was stuck. Worked stuck gun. NOW: Working s~tuck gun. Worked stuck perf gun - finally pulled loose. POOH w/ WL - WL-stranded in grease head. Repaired same. POOH w/ WL - perf gun parted above top shot. Left entire 14' gun in hole. Disp DP w/ 91 PCF mud. Released RTTS & POOH w/ DP. Laid down test tools - gun had fallen out in hole. RU GO WL.w/ OH lubricator. .RIH w/ 14' of 4" casing guns & perfed' DST #4 f/ 9386' to 9400' DIL. POOH w/'perf gun. RIH w/ test tools (60' tubing tail, RTTS, bundle carrier, and aux valve) on 3 1/2" DP w/ 500' water cushion. Test manifold & lines to 6000 psi. Set RTTS @ 9274', tail @ 9340' DPM. Opened aux valve & had moderate blow in bubble bucket. Tested for 1 hour w/ no increase. Re- leased RTTS & reversed out to kill well- rec sand to surface. RIH w/ 2 jts to 9408' & rev clean. NOW: Circ hole clean. · UNION OIL Ca'?A N [F CALIFORNIA ELL-RECORD SEEET D PAGE ih....2o LEASE FEE T,~ASE - FREDRICKSON ELL NO, #3 FIELD DATE 80 8/13/81 DAILY COST' ACC COST' AFE AMT: 81 8/14/81 DAILY COST: ACC COST: AFE AMT' ETD 11125' TD 9280' ETD '(RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 50 SEC $ 41,495 $4,404,432 '$2,813,000 11125' TD · 9280' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 84 PCF 52 SEC $ 43,113 $4,447,545 $2,813,000 · .DETAILS OF OPEPATIOItS, DES.CRIpTIOI!S & RESULTS Circ hole clean of sand f/~DST #4. Picke~ up 2 jts'& shut well' in for 2 hrs. POOH .w/ DP. RIH w/ 7" cmt ret on DP & set @ 9280.' DPM. Test sqz manifold & lines to 6000 psi. Broke down DST #4 perfs f/ 9386' to 9400' DIL w/ 2400 psi. Pumped in w/ 2 BPM.@ 2500 .pSi. Formation held 1900 psi after 2 min. Mixed & pumped 300 sxs CL "G" w/ 8 gal/lOO, sxs R-12L & 1 gal/lO0 sxs D-6L to lq9 PCF. Disp 280 sxs below ret w/ a final rate of 2.5 BPM @ 2900 psi. Sqz held 2000 psi after 2 min. CIP @ 12:00 hrs 8/13/81: Rev out 20 sxs cmt. POOH w/ DP & LD 120 jts. RU GO WL & RIH w/ 4" csg gun. Perfed 4-1/2" HPF f/ 7246' to 7248' DIL for isolation BS #9. RIH w/ 9 5/8" cmt ret on WL to 7222' DIL & attempted to set ret. Retainer would not set. POOH - ret stuck.@ 5350' WLM.- NOW: Working stuck ret. Worked stuck ret. Pulled out of rope socket w/ 4350# pull. POOH w/ WL.- RIH w/ guide, 2 7/8" OS, 2 ext., bumper sub, & jars. Tagged fish @ 5468" DPM. Latched onto fish & pulled free w/ 2OM# pull.' POOH. Rec setting tools - left ret in hole. (Note: Charges on setting tool did not fire). RIH w/ 8 1/2" bit & 6 1/2" DC's. Tagged ret @ 5468' DPM. Drld on ret 1/2 hr & pushed ret to 7750' DPM. Circ btms up & POOH w/ DP. Ran GR & JB to 7750' - POOH. RIH w/ cmt ret on WL & set ret @ 7222' DIL. POOH w/ WL. RIH w/ stab-in tool on 3 1/2" DP. NOW' RIH w/ stab-in tool. OIL CO[?At Y a: CALIFO .iI^ ELL RECORD SI.:EB' D ih, -.. LEASE FEE ~E - FREDRICKSON 'ELL I O, CLU #3 FIELD WI T DATE 82 8/15/81 DAILY COST: ACC COST: AFE AMT: 83 8/16/81 DAILY COST: ACC COST: AFE AMT: ETD 11125' TD 7109' ETD (RET) 9 5/8" C. 8!30' 7" L. 11125' to 7783' 81PCF 47 SEC $ 36,337 $4,483,882 $2,813,000 11125' TD 6040' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 81 PCF 46 SEC $ 51,065 $4,534,947 $2,813,000 .DETAILS OF .OPE~TiO[!S, DESCRIpTIO~!S ~ RESULTS Fin RIH w/ DP. Tagged ret @ 7230' DPM. RU sqz manifold & surf lines & tested to 6000 psi. "teSted csg to 2000 psi. Broke down perfs f/ 7246' to 7248' DIL w/ 2100 psi.' Pumped in w/ 3 BPM @ 2200 psi. Formation held 1500 psi w/ pumps off 1 min. Mixed & sqz'd w/ 250 sxs cl "G" w/ 3 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L for BS #9. Dis- placed 230 sxs below ret w/ a final rate of 3 BPM @ 2500 psi. Sqz held 1750 psi w/ lpumps off after 1 min. CIP @ 03-05 hrs 8/15/81. Rev out 20 sxs cmt. POOH w/ DP. WOC for 12 hrS~ RU GO WL & perfed 4-1/2" HPF f/ 7187' to 7189' DIL for BS #10. POOH w/ WL. RIH w/ 9 5/8" cmt ret on DP & set ret @ 7109' DPM., RU .& tested sqz manifold & surf lines to 6000 psi. Broke down perfs w/ 2200 psi. Pumped in w/ 3 BPM @ 2100 psi. Formation held 1100 psi w/ )umps off'l min. Mixed & sqz'd w/ 250 sxs 1 "G" w/ 3 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L for BS #10. Displaced 230 sxs below ret w/ a final rate of 2 1/4 BPM @ 1800 psi. Sqz held 1400 psi w/ pumps off 1 min. CIP @ 20:15 hrs 8/15/81. Rev out 20 sxs cmt. POOH w/ DP. RU GO WL. NOW: Prep to perf for BS #11. RIH w/ GO W1 & perfed 4-1/2" HPF f/ 6175' to 6177' DIL. RD GO WL. Dropped chain binder in hole. Checked BOP stack. Ran GR & JB to 7090' WLM (ret). POOH w/ WL. RIH w/ cmt ret on 'WL & set @ 6131' DIL. POOH w/ WL. RIH w/ stab-in tool on DP & tagged ret @ 6137' DPM. RU & tested sqz manifold to 6000 psi. Broke down perfs w/ 2000 psi. Pumped in w/ 5 BPM @ 3000 ipsi. Formation held 1100 psi w/ pumps off i1 min. Mixed & sqz'd w/ 250 sxs cl "G" iw/ 3 gal/lO0 sxs R-12L & 1 gal/lO0 sxs,D-6L for BS #11. Displaced 234 sxs below ret w/ a final rate of~2 BPM @ 3750 psi. Sqz held 2000 psi w/ pumps off 4 min. CIP @ 07:40 hrs 8/16/81. Rev out 16 sxs cmt. POOH w/ DP. WOC 12 hrs. RU GO WL & perfed 4-1/2" HPF f/ 6091' to 6093' DIL. POOH w/ WL. RIH w/ 9 5/8" ret on DP & set ret @ 6040' DPM. NOW: Prep to sqz for BS #12. OIL OF CALIFO iIA ~ELL RECORD · $}:~-'F D PAGE ih. -'~- LEASE ~E ~E - FRED~C~ON WELL I,IO, CLU #3 FIELD WIIf)C2~T DATE 84 8/17/8' DAILY COST: ACC COST: AFE AMT: ETD 11125' TD 6040' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 82 PCF 47 SEC $ 43,627. $4,578,574 $2,813,000 DE.TAILS_OF OPERATIOI!S, DESCRIPTIO{!S ~ _RESULTS ~U sqz'manifold & tested to 6000 psi. Tested csg to 2000 psi. Broke down perfs v~/ 1750 psi Pumped in w/ 3 1/2 BPM @ 1750 psi. ~ormation h61d 1000 psi after 1 min. Mixed & sqz'd perfs f/ 6091' to 6093' DIL w/ 250 sxs CL "G" w/ 3 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L. for BS #12. Displaced 235 Sxs below tool w/'a final rate of 3 BPM @ 2500 psi. Sqz held 1500 psi after 1 min. CIP @ 00:15 hrs 8/17/81. Rev out 15 sxs cmt. POOH w/ DP. RU GO WL & perfed 4-1/2" HPF f/ 5832'-to 5834' DIL. POOH w/ WL. RIH w/ 9 5/8" cmt ret on WL & set @ i800' DIL. POOH w/ WL. RIH w/ stab-in :ool on DP & stabbed into ret @ 5807" }PM. Attempted to break doWn perfs - :ould not. Annulus was taking fluid. Recorrelated strip log & found holes actually shot at 5796' to 5798' DIL. POOH w/ DP. RIH w/ 8 1/2" bit & junk sub & drld &'pushed ret to 6040' DPM. Circ & POOH Ran GR & JB to 6040'. POOH. RIH ~/ perf gun & perfed f/ 5832' to 5834' DIL for BS #13. NOW: ~ POOH w/ WL. U[1IOi.l OIL CCI?A IY CALIFOPJ.iIA ELL RECORD SI<ED' D PAGE ;b. LEASE .. 1~, T.F~E- FRFI~RICKSON WELL l O, FIELD rvv-I T DATE 85 8/18/81 DAILY COST' ACC COST' AFE AMT' ETD 11125' TD 5590' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 82 PCF 47 SEC $ 68,783 $4,647,357 $2,81 3,000 DETAII_.S OF OPERATIOItS,_ DESCRIP.!IOI!S ~ RESUL.TS POOH w? WL. RIH w/ cmt ret on WL & set @ 5815' DIL. POOH w/ WL. RIH w/ stab-i~ tool~On DP & stabbed into ret @ 5824' DPM.. Tested surf equip to 6000 i. Broke down perfs f/ 5832' to 5834' DIL w/ 1700. psi. Pumped in w/ 3 BPM @ 2250 psi' (had circ back to annulus). Formation held 1750 psi w/ pumps Off. 1 min..~ Mixed & pumped 100 sxs cl "G" w/ 3 gal/lO0 sxs R-12L & 1 gal/lO0 sxs' D-6L~to 119 PCF. Displaced 80 sxs below ret w/ a final, rate of 2 3/4 BPM @ 1500 psi. CIP @ 05:00 hrs 8/18/81. Pulled ~up to 5790' iDiL & rev out 25 sxs cmt. POOH w/ DP. WOC 4 hrs. RIH w/ GO WL & perfed 4-1/2" HPF f/ 5779', to 5781' DIL for BS #14. POOH w/ WL. RIH w/ cmt ret on DP & set ret @ 5720' DPM. Pest surf equip to 6000 psi. Broke down )erfs w/ 1600 psio Pumped in w/ 5 BPM 1900 psi. Formation held 650 psi w/ )umps off 2 min. MiXed & sqz'd w/ 300 sxs ;1 "G" w/ 3 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L to 119 PCF. Displaced 280 sxs below ret w/ a final rate of 4 BPM @ 2400 psi. Sqz held 1400 psi w/ pumps off 1 min. CIP @ 14'28 hrs 8/18/81. Rev out 20 sxs cmt. POOH w/ DP. RU GO WL & 4-1/2" HPF f/ 5601' to 5603' )IL for BS #15. RIH w/ cmt ret on WL & set 5585' DIL. POOH w/ WL. RIH w/ stab-in tool on DP & tagged ret @ 5590' DPM..Tested surf equip to 6000 psi. Broke down perfs w/ 1500 psi. Pumped in w/ 6 BPM @ 2000 psi. Formation held 900 psi w/ pumps off 1 min. 'Mixed & sqz'd w/ 250 sxs cl "G" w/ 3 gal/lO0 sxs R-12L & 1 gal/lO0 sxs D-6L to 119 PCF. iDisplaced 220 sxs below ret w/ a final rate of 4 BPM @ 2000 psi. Sqz held 1100 psi w/ off 1 min. CIP'@ 22'00 hrs 8/18/81. :v out 30 sxs cmt. WOC 12 hrs. ~OW' Prep to POOH w/ DP. · o OIL CO/PA N · CALIFOPJiI^ ELL RECORD SI-:EET D PAGE ih...24 LEASE FEE LEASE - FREDRICKSON [LL l O, #3 FIELD · TATI T DATE 86 8/19/81 DAILY COST' ACC COST' AFE AMT' 87 8/20/8: DAILY COST' ACC COST: AFE AMT' 88 8/21/81 DAILY COST' ACC COST' AFE AMT: ETD 11125' TD 5394' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7.783' 82 PCF 57 SEC $ 50,816 $4,698,173 $2,813,000 11125' TD 5490' ETD (RET) 9 5/8' c. 813o' ' 7" L. 11125' to 7783' 78 PCF 47 SEC $ 28,886 $4,727,O59 $2,81 3,000 11125' TD 5815' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 77 PCF 50 SEC $ 28,115 $4,755,174 $2,813,000 ...... , .&_RESULTS ~DETAILS OF OPEP~TiO[tS DESCRIRTIO[!S )OOH' w/ DP. WOC. RU GO WL & perfed 4-1/2".JJPF w/ 4" csg guns f/ 5565' to 5567' DIL for~BS #16. POOH w/ WL. RD CO WL. RIH w/ 9 5/8" cmt ret on 3 1/2" DP & set ret @ 5484' DIL (5490' DPM). Installed & tested surf equip to 5000 )si. Tested csg to 3000 psi. Broke down )erfs w/ 1500 psi. Pumped in w/ 4 BPM 2000 .psi. Formation held 800 psi w/' )umps off 5 min. Mixed & sqz'd w/ 200 ;xs cl "G" w/ 3 gal/lO0 sxs R-12L & 1 gal/100 sxs D,6L. to 119 PCF. Displaced 90 sxs below ret w/ a final rate of 1/2 BPM @ 2500 psi. Sqz held 1500 psi ~/ pumps off 5 min. CIP @ 13:20 hrs B/19/81. Rev out lO sxs cmt. POOH w/ DP. RU GO WL. Perfed 4-1/2 HPF f/ 5412' - 5414' DIL for BS #17. POOH w/ WL. RIH ~/ 9 5/8" ~cmt ret on WL & set ret @ 5394' DIL (5400' DPM). POOH w/ WL. RIH w/ ;tab-in tool on 3 1/2" DP. Tested surf ~quip to 5000 psi. Tested csg to 3000 psi. Broke down perfs .w/ 1700 psi. Pumped in w/ 5 BPM @ 1800 psi. Formation leld 800 psi w/ pumps off 5.min. Mixed ~ sqz"d w/ 200 sxs cl "G" w/ 1 gal/lO0 sxs D-6L to 119 PCF. Displaced 190 sxs below ret w/ a final rate of 4.5 BPM @ 2500 psi. Sqz held 1500 psi after 5 min. CIP @ 20:50 hrs 8/19/81. Rev out 10 sxs cmt. POOH w/ DP. NOW' Laying down 4 3/4" DC's - WOC. LD 4 3/4" DC's. RIH w/ 8 1/2" bit & junk sub on 6 1/4" DC's to 5000'. WOC. RIH & drld on ret @ 5394' DPM. Drld 30' of firm cmt below ret & drld on ret @ 5490' DPM. Bit stopped. POOH. RIH w/ bit #37 & drld on ret @ 5490'. NOW' Drlg on re~ @ 5490'. Drld out ret @ 5490' & drld firm cmt to 5590'. Drld ret @ 5590' & drld firm cmt to 5720'. Drld on ret @ 5720' POOH for bit chg. RIH w/ bit #38. Drl~ ret @ 5720' & firm cmt to 5824'. Drld on ret @ 5824'. NOW' Drlg ret @ 5824'. UiilOIl OIL CCl?AI f CF CALIFOP iIA ELL SHEET D LEASE FEE LEASE - FREDRICKSON DATE 89 8/22/81 'DAILY COST: ACC COST: AFE AMT: 90 8/23/81 DAILY COST: ACC COST: AFE AMT: 91 8/24/81 DAILY COST: ACC COST: AFE AMT: 92 8/25/81 DAILY COST: ACC COST: AFE AMT: ETD 11125' TD 6137' ETD (RET) 9 5/8" c. 8]30' 7" L. 11125' to 7783' 77 PCF 47 SEC $ 30,298 $4,785,472 $2,813,000 11125' TD 7098' ETD (FISH) 9 5/8" C. 8130' 7" L. 11125' to 7783' 77 PCF 51 SEC $ 24,637 $4,810,108 $2,813,000 11125' TD 7104' ETD (FISH) 9 5/8" C. 8130' 7" L. 11125' to 7783' 78 PCF 48 SEC $ 23,284 $4,833,392 $2,813,000 11125' TD 7109' ETD (RET) --9 5/8" C. 8130' 7" L. 7783' to 11125' 78 PCF 47 SEC $ 33,509 $4,866,901 $2,81 3,000 ELL NO, #3 FIELD DETAILS OF 0PEPATIOlIS, DgSC_RIPTIOf!S_~.,RESULTS P00H.of/ bit chg. RIH w/ bit #39 & drld ret @ 5824'~ Drld firm cmt f/ 5824' to 5893'. RIH & drld on ,junk ret @ 6040'. POOH f/ bit chg. RIH w/:bit //40 & drld 2 rets at 604,0'. Drld firm cmt to 6137'~ NOW: .Drlg_ret @ 6137'. , . Down 2 hrs to repair mud line. Drld on ret @ 6137'. Trip for bit. chg_ RIH w/ bit #41 & drld ret @ 6137',.Drld cmt to 6312' RIH to 7098' & set' down w/ 5000# (ll' a6ove ret). Circ on fish w/ 5000# down - would not pump off. POOH w/ DP. RIH w/ burn-over shoe.,(sawtooth) w/ rev circ junk basket. NOW: RIH w/ fishing tools. RIH w/ BO shoe & rev circ JB. Set down @ 7098' w/ 5M#. Dropped ball to rev circ & rotated down to 7098'. Initially took weight then dropped 8". BO 6" & POOH. Rec 2 small pcs of cmt & a bit tooth. Reran BO shoe & JB to 7099'. Burned over 2' & POOH. Rec cmt & ret junk. RIH w/ BO shoe, JB, & 18' of wash pipe. Tagged @ 7100' & rotated down to 7104' - began to get metal cuttings back. POOH. Rec a cmt core. (Note' lost carbide o~f leading edge of shoe). RIH w/ BO shoe & JB. NOW: RIH w/ fishing assy. RIH w/ shoe #3 (trip #4 w/ JB). BO junk @ .7107' ~iMade 4 to 5II in 3 hrs. POOH. Rec c~ai~ binder parts in boot basket - nothing in JB. RIH w/ shoe #4 (trip #5 w/ JB). BO junk @ 7107'. Made 2 1/2" in 5 1/2 hrs. POOH. Rec misc binder parts in boot basket - nothing in globe JB. LD wash pipe & globe JB. RIH w/ 8 1/2" OD concave junk mill. Milled on junk f/ 7107' to cmt ret @ 7109'. NOW: Milling on cmt ret @ 7109'. U[i[O l OIL Ca:PA Y CALIFOR IIA ELL RECORD PAGE LEASE Flqlq T,VASE - FREDRICKSON DATE 93 8/26/8l DAILy COST' ACC COST' AFE AMT' 94 8/27/81 DAILY COST' ACC COST' AFE AMT' 95 8/28/81 DAILY COST' ACC COST' AFE AMT' ETD 11125' TD 7230' ETD (RET) 9 5/8" C. 8]30' 7" L. 11125' to 7783' 78 PCF 43 SEC $ 23,849 $4,89O,75O $2,813,000 11125' TD 7770' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 79 PCF 42 SEC $ 34,638 $4,925,388 $5,878,000 11125' TD 7770' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 82 PCF 43 SEC $ 40,585 ,$4,965,973 $5,878,OOO ELL l lO, #3 FIELD ._DETAILS OF OPERATIO[IS, DESCRIpTIOI!S .2~ RESULTS Continued to mill on ret @ 7109' · POOH.. Rec retainer junk i.n boot basket. RIH w/ 8 1/2" bit #42 & tagged ret @ 710.9', Drld ret @ 7109' .& firm cmt down to ret @ 7230'.. Drld on ret @ 7230'. POOH for bit change. NOW- Trip for bit change. RIH w/ .bit #43 & drld ret @ 7230'. Drld firm cmt to 7326'. RIH & tagged junk ret @ 7770'. Circ clean & POOH. RU GO WL & ran CBL-VDL-GR-CCL log f/ 7700' to 5000'. RD GO WL. RIH w/ 8.1/2" bit & csg scraper to 7770'. Circ clean. NOW: CIrc hole clean. Circ clean & POOH. RIH w/ RTTS pkr w/ aux valve on dry DP. Set RTTS pkr @ 5364' & opened aux valve - well was dead in 1 1/2 hrs. Released RTTS & RIH to 7400' DPM. Circ & POOH. RIH w/ DST tools (RTTS, bundle carrier, & aux valve) on dry DP. Set RTTS @ 7091' DPM. Tested surf equip to 5000 psi. 'RU GO WL & tested lubricator to 5000 Psi. RIH w/ 8' link-jet 2 1/8" perf gun to '7200'. Loaded DP w/ 2100 psi nitrogen cushion. Perfed upper portion of DST #5 f/ 7194' to 7202' DIL. Saw no increase in surf pressure. POOH w/ WL. NOW' Prep to p.erf lower portion of DST #5. UNION OILCF CALIFORI. IA ELL RECORD SI-:EET D _ LEASE - NELL NO, #3 FIELD DATE 96 8/29/81 DAILY COST: ACC COST: AF'E AMT: 97 8/30/81 DAILY COST: ACC COST: AFE AMT: ETD 11125.' TD 7770' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 82 PCF 43 SEC $ 39,540 $5,005,513 $5,878,000 11125' TD 7092' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 83 PCF 41 SEC $ 54,247 $5,059,760 $5,878,000 OF Loaded 8' perf gun in lUbricator & RIH. Perfed lower portion of DST #5 f/ 7230' to 7238' DIL. Saw no increase in surf pressure. POOH w/ WL. Bled off nitrogen cushion - well was dead. -RIH w/ 10' perf §un - gun stuck @ 7020' WLM. Worked stuck perf gun .- pulled loose & PooH-. Left 5' of perf gun in hole. Released RTTS & rev clean. RIH to 7284' DPM & rev clean. POOH & LD test tools..RU GO WL & perfed DST #5 f/ 7228' to 7238' DIL & 7192' to 7202' DIL'w/ 4" csg guns. RD GO WL. RIH w/ DST tools (RTTS pkr & bundle carrier) to 7156'. Rabbited DP & rec. 5' perf gun. Tested surf equip to 500.0 psi & displaced fluid in DP w/ nitrogen (surf pressure of 3315 psi). Set RTTS pkr @ 7089', tail @ 7156'. Bled off nitrogen & DP pressure bled to Opsi. Released RTTS pkr & rev 'circ&~mc sand). RIH to 7280' & rev circ. Pulleu up to 7189' & prep to acidize DST #5 perfs. NOW: Acidizing DST #5 perfs. Pressure tested lines. Pumped into perfs w/ 1600 psi @ 1.1 BPM. Form held 1300 psi w/ pumps off 1 min. Released RTTS. Pumped down DP w/ 20 bbls water, 250 ga! 7 1/2% HCL, 800 gal 7 1/2 - 1 1/2% mud acid, and 250 gal 7 1/2% HCL (all acid w/ .5% F75N surfactant and '.8% A-200 inhibitor). Displaced acid to RTTS w/ nitrogen (1620 psi at surf). Set RTTS & acidize DST #5 perfs by displacing w/ nitrogen (3920 psi max). Shut well in - for 1 hr. Bled off nitrogen thru 3/8" choke - well bled to 0 psi. Shut well in & pressure built to 17 psi in 1.5 hrs. Released RTTS pkr & rev out. Remove test head .& RIH to~7283' & rev clean - rec lrg. grained sand~ C&C mud. POOH w/ test tools. LD 1000' of DP & all HWDP in derrick. RIH w/ cmt ret on DP & set ret @ 7092' DPM. Tested surf equip to 5000 psi. Broke down perfs w/ 1900 psi. Pumped in w/ 3 BPM @ 2000 psi. Form held 1300 psi w/ pumps off 2 min. Mixed & sqz'd w/ 150 sxs cl "G" w/ 3 gal/lO0 sxs R-12L & 1 gal /100 sxs D-6L to 118 pcf. Displaced 147 sxs below tool with a final rate of 3 BPM @ 2000 psi. Sqz held 120.0 psi w/ pumps off 1 min. CIP @ 21:07 hrs 8/30/81. Rev out 3 sxs cmt. POOH w/ DP. NOW: POOH - LD llO0' of DP. OIL Ca'?A h' · CALIFORRIA ELL RECORD S}:EET D PAGE ih, e8 LEASE FEE LFASE - FREDRICKSON DATE 98 8/31/81 DAILY COST' ACC ,COST' AFE AMT' 99 9/1/81 DAILY COST' ACC COST' AFE AMT: ETD 11125' TD 7092' ETD (RET) 9 5/8" C. 8]30' 7" L. 11125' to 7783' 83 PCF 40 SEC $. 49,715 $5,109,475 $5,878,000 .. 11125' TD 6050' ETD (RET) 9 5/8" C. 8130' ~7" L. 11125' to 7783' 84 PCF 41 SEC $ 37,265 $5,146,740 $5,878,000 'ELL #3 FIELD ..DETA.Ii[.S OF OPEP&TIOIIS,. DESCRIPTIOI!S ~.FqESUL,TS. POOH & LD 1100' of DP. 'RIH w/ DST tools (60" tail, RTTS, bundle carrier, aux valve). Tested surf equip to 5000 psi. Set RTTS @ 6000' DPM. RIH w/ 16' of 2 1/8" link-jet perf gun. Put 1800 psi. nitrogen cushion in DP. Attempted to..perf DST #6 f/ 6156' to 6172' DIL. Saw no pressure increase. Bled cushion off slowly - well bled to 0 psi. POOH w/ WL - guns had not fired due to bad prima cord. RIH w/ 16' perf gun & put 1800 psi 'nitrogen cushion in DP. Perfed f/ 6156' to 6172' DIL - saw no pressure increase. POOH w/ WL. Guns had not fired due to bad prima cord. RD GO WL. RU Schlumberger. RIH w/ 16' of 2 1/8" enerjet guns and perfed DST #6 f/ 6156' ..to 6172' DIL. Saw no pressure increase.. POOH w/ .WL '- guns had fi red. Bled nitrogen to 1000 psi & shut in - saw no pressure increase. Bled nitrogen to 600 psi & shut-in. RIH w/ 16' perf gun & reperfed DST #6 f/ 6156' to 6172' DIL w/ no in- crease in surf Pressure. POOH w/ WL - tools stuck @ 3230' WLM. Worked stuck tools ~while well shut-in. NOW' Working stuck WL tools. Bled off 600 psi nitrogen cushion @ 00'30 hrs. Shut well in & worked stuck tools. Filled DP w/ mud & pulled up to 3000# on WL - would not pull looSe. Cut WL & LD lubricator. Released RTTS & circ down DP while working WL. Pulled up to 3000# & WL pulled free. POOH w/ WL - found WL pulled out of rope soCket. RIH w/ 2 stds of DP to +6252' Circ btms up - rec sand.- PO0~ and rabbit d.p. - did not~ find W.L. tools. RIH w/ cmt. ret. on d.p. and set ret. @ 6050' D.P.M, Tested surface equip. to 5000 psi. Broke down DST #6 perfs. F/ 6156' to 6172' DIL w/ 2000 psi. · Pumped in w/ 4 BPM @ 2750 psi. Formation held 1650 psi w/ pumps off 2 min. Mixed and squeezed w/ 250 sx. cl. "G" w/ 3 gal/lO0 sx. R-12L and 1 gal/lO0 sx. D-6L to 119 PCF. Dis- placed 230 sx. below ret. w/ a final rate of 3 BPM @3400 psi. Sqz. held 1800 psi w/ pumps off 1 min. CIP @ 15:35 hrs. 9/1/81. Reversed out 20 sx. cmt. POOH w/ d.p. laid down tools. RIH w/ DST tools - rabbi ted d.p. NOW: Testing surface lines. · . UNION OIL Ca2/ N CF CALIFORI IA ELL E¢ORO S}:EET D P^ z lb, ,,_ LEASE ~ ~lq, - FREDRICKSON DATE ETD lO0 9/2/81 DAILY COST' ACC COST' AFE AMT' 11125' TD · 6050' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 82 PCF 40 SEC $ 49,828 $5,196,568 $5,878,000 ~l~LL [~0, CLU #3 FIELD .DETAILS OF_.OPEPATIO[IS, DESCRIpTIOI!S .& RESULTS. · · Tested surf lines to 5000 psi. Set RTTS pkr @ 5682', tail @ 5748', RU & tested lubricator, RIH w/ 8' of of 2 1/8" enerjet perf gun - gun stopped @.5695' WLM (aux valve). Worked gun loose, Attempted to log down w/ CCL to determine exact .position - gun. stopped @ 5690'.- worked gun loose. POOH & checked guns - ok, RIH w/ 2 1/16" sinker bars - stopped @ 5690', PU & retorqued aux valve - gun would not go below 5690', POOH, Removed lubricator. Released RTTS & rev circ - rec contaminated mud. Circ clean, RIH w/ sinker bars - got thru tools ok, RIH w/ perf gun ' got thru tools ok, POOH, Displaced mud in DP w/ nitrogen to 2700 psi. Set RTTS @ 5682' & bled off nitrogen cushion to 1600 psi. RU lubricator & RIH w/ 8' perf gun, Perfed middle part of DST #7 f/ 5804' to 5812' DIL - saw no pressure increase, POOH w/ gun. RIH w/ 10' of 2 1/8" enerjet guns & perfed lower part of 'DST #7 f/ 5818' to 5828' DIL. Had i.mmediate pressUre increase f/ 1580 psi to 1620 psi. Bled off nitrogen & fl owed well thru 3/8" & 3/4" choke until cleaned !up..Turned well to flare @ 17'40 hrs. Well had initial rate of 3.25 MMCFD @ 1050 psi w/ 200 BPD fluid @ 18-05 hrs. Well made final rate of 4.6 MMCFD @ 1150 psi. w/ 68 BPD fluid prior to shut-in @ 19:40 hrs. The well was also making sand. Left well shut in 4 hrs. until 23:40 hrs w/ a final pressure of 2092 ps i. NOW' Prep to run temp survey, · OIL CD?f rf CF CALIFOF iIA ELL RECORD _ D LEASE 5~EE LEASE - FR]~I)P~CICSON DATE ETD ]0] 9/3/8] 11125' TD 6050' ETD (RET) 9 5/8" C. 8130' 7" L. 11125" to 7783' 81PCF 4O SEC DAILY COST: $ 43,299 ACC COST: $5,239,867 AFE AMT: $5,878,000 102 9/4/81 11125' TD 6050' ETD (RET)' 9 5/8" C. 8130' 7" L. 11125' to 7783' 81 PCF 40 SEC DALLY COST: $ 52,389 ACC COST: $5,292,256 AFE AMT: $5,878,000 ~l~kk [~0, CLU #3 FIELD DETAILS OF OPEPj%T. IO[tS,_ DESCRIPTIOI!S & RESULTS. .' · . Attempted to test lubricator - no good. Repacked grease head & tested l ub to 4000 psi ~ ok. RIH w/ temp survey tool - tool failed. POOH. Reheaded WL.. Retested lubricator & RIH. Ran static temp survey f/ 5000' to 6000'. POOH. RU to run 8' perf gun - gun would not drop out of lubricator. Flowed well lO min then shut in -.. 'tools would not drop out of lubricator. Changed out grease head & cut off 100' of_ WL;. Reheaded perf gun & tested l ub to 4000 psi. RIH w/ 8' perf gun. Flowed well for 20- min w/ gun in hole. Shut well in & perfed the upper pOrtion of DST #7 f/ 5788' to 5796' DIL. POOH w/ perf gun. Flowed well for 4 hrs - had final rate of 5.32 MMCFD w/ 1233 psi DP pressure. Well also made a rate of 19.2 BWPD. Loaded temp survey tool while flowing well. Shut well in & ran temp survey tool in hole. F1 owed well for 20 min & ran flowing temp survey f/ 5791' to 6000'. Shut w, ell in and ran static temp survey f/ 5000 to 6000'. POOH w/ WL. . NOW: Prep to run HP recorder. RIH w/ GO WL. HP pressure recorder on Schlumberger WL - tool quit while RIH. POOH & changed out tools. At- tempted to test lubricator - master valve & lubricator valve would not hold pressure. Killed well w/ 20 bbl CaC03 pill across perfs. Removed test manifold & installed safety valve on DP. Well began to flow up DP (bub- bles migrating thru mud). Released pkr & rev circ until well was dead. PU & removed 21' pup jt. Installed & tested new test manifold. Displaced mud w/ nitrogen. Reset RTTS pkr @ 5661', tail @ 5727' Bled off cushion & opened well '@ 10'~0 hrs. Flowed well until 16:'15 hrs to clean up. Well stabilized @ 5.25 MMCFD @ 1150 psi. Shut in well @ 16:15 hrs. RIH w/ HP recorder to 5770' WLM. Down 3 1/2. hrs while repairing variable choke on heater. Opened well to flow @ 21:30 hrs. NOW: FlOwing well. U[iIOIt OIL COI2At ¢ CF CALIFOP IIA ELL RECORD S 2ET D · P^ E ih..3.]. LEASE ~qqlq !,FASE ,- FREDRICKSON NELL cmu #3 FIELD O,A, TE 103 9/5/81 DAILY COST' ACC COS1' AFF AMT' · · 104 9/6/81 DAILY COST: ACC COST' AFE AMT' 105 9/7/81 DAILY COST' ACC COST' AFE AMT' ETD 1i125' TD 6050' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 81 PCF 40 SEC $ 50,549 $5,342,805 $5,878,000 11125' TD 5762' ETD (cmt) 9 5/8" C. 8130' 7" L. 11125' to 7783' 81 PCF 40 SEC $ 35,564 $5,378,369 $5,878,000 11125' TD 5555' ETD (CMT) 9 5/8" c. 8]30' 7" L. 11125' to 7783' 81 PCF 39 SEC $ 28,599 $5,406,968 $5,878,000 _DETAILS OF OPEPATIOItS, D~SCRIPTIO[!S .& RESULTS Flowed well @ 5.5 MMCFD @ ll20 psi. Shut well in @ 02:30 hrs. Opened well for 4 point test @ 08:30 hrs. Flowed well for 1 hr - made 2.09 MMCFD rate @ 1860 psi w/ 0 BWPD. Shut well in 1 hr. Opened well for 1 hr for 2nd point -_made 2.89 MMCFD @ 1774 psi wl 0 BWPD. Shut well in 1 hr. Opened well for-1 hr for 3rd point.- made 3.65 MMCFD @ 1654.psi w/ 0 BWPD. Shut well in 1 hr.":' -. "Opened well. for 1 hr for 4th point - made 5.3 MMCFD @ 1320 psi w/ 19.2 BWPD. , Completed'4 point test @ 15:30 hrs. POOH w/ WL. Spotted 20 bbl CaC03 pill across perfs to kill well. Released pkr & rev clean. RIH w/'.l 2/3 stds of ~ DP - tagged fill @ 5992'. PU to 5977' I & circ clean. POOH w/ DP. , NOW: LD DST tools. Finished LD DST tools. RIH w/ OEDP & tagged fill @ 5950'. Circ down to 5955'. Equalized 130 sxs cl "G" cmt in pipe ('est TOC @ 5600'). CIP @ 03:55 hrs. POOH & LD 8 stds of DP. RIH w/ 8 1/2" bit on 6 1/4" DC's to 5000' - WOC 9 hrs. RIH & tagged cmt @ 5671' - cmt still soft. POOH w/ DP. Found 1 extra stand of DP in ho'le - TOC @ 5762' DPM (22' above top of perfs). RIH w/ test tools. Set RTTS pkr @ 5444', tail @ 5514'. Opened aux valve and confirmed no entry. Put 1550 psi nitrogen cushion on DP. RIH w/ 10' of 2 1/8" enerjet perf gun. NOW: Prep to perforate DST #8. Perfed DST #8 f/ 5584' to 5594' DIL. Had no surf pressure increase. POOH w/ WL. Bled N2..cushion to 800 psi. RIH w/ 10' perf gun - press built to 1072 psi in 2 hrs. Bled off to 770 psi. .Reperfed DST #8 f/ 5584' to 5594' DIL. Opened well & bled off cushion - had no flow. POOH w/ WL. Shut well in. Press built to 1 psi after 2 hrs. Filled DP, released pkr, & rev circ clean. RIH w/ 2 stds DP to 5699' & rev circ clean (rec sand). POOH - LD test tools.- RIH w/ OEDP & tagged cmt @ 5762'. Hung OEDP @ 5761' & equalized in 110 sxs cl '°G" w/ 8 gal R-12L. CIP @ 14:00 hrs. POOH. RIH w/ 8 1/2" bit on 6 1/4" DC's to 4500' - WOC. RIH & tagged cmt @ 5520' (58' low). CO firm cmt to 5555'. Circ clean. NOW- Circ hole clean. U:'IIOil OIL Ca?AllY CALIFOI :IA · . ELL RECORD D PAGE ih. LEASE FEE LFASE - FREDRICKSON ~I~LL I~O, c~u #3 FIELD DATE 106 9/8/81 DAILY COST' ACC COST' AFE AMT' 107 9/9/81 DAILY COST' ACC COST' AFE AMT' ETD 11125' TD 5555' ETD (CMT) 9 5/8" c. 8130' 7" L. 11125' to 7783' 80 PCF 47 SEC $ 44,024 $5,450,992 $5,878,000 11125' TD 5555' ETD (CMT) 9 5/8" C. 8130' 7" L. 11125' to 7783' 82 PCF 57 SEC $ 41,969 $5,492,961 $5,878,000 DETAILS _OF .PPEP~TIO[tS, DESCRIPTIO[!S &]RESULTS , · Finished circ well clean. POOH. RIH w/ DST toOls Tested manifold to 4000 psi. Set pkr @ 5284", tail @ 5354'. Opened aux valve & confirmed no entry. Charged DP w/ 1500 psi N2 cushion. RIH w/ !'2' of 2 1/8" enerjet gun & perfed DST #9 f/ 5508' to 5520' DIL. Had no increase in surface pressure. POOH w/ WL - noticed slow surface pressure in- crease~to 23 psi. Stuck WL tools @ 3302' WLM (ccl depth) - could not work loose Surface pressure had increased from 1430 psi. to 1551 psi. Put tension in drill string & increased N2 cushion to 3000 psi.- tools still stuck. Opened well'& blew off cushion tools still -stuck. Blew cushion down to 0 psi - had.no .entry.. Released pkr & rev circ- had some-restriction in DP. Circ down DP - could not free WL tools. 'Confirmed well dead. Removed lubridator & manifold. Cut WL & POOH w/ DP & WL simultaneously. NOW: POOH w/ DP & WL. POOH w/ DP & ~L. Found WL tools in 36th std of DP]- no obvious reason for sticking..Finished POOH w/ DP. RIH w/ 8 1/2" bit to 5555' & circ clean. POOH. RIH w/ DST tools - rabbited pipe & tools. Set pkr @ 5288', tail @.'5354' RU & tested surface equip to 40~0 psi. Charged DP w/ 1500 psi N2 cushion. Opened aux valve & RIH w/ 12' perf gun. Stuck gun while locating in tools @ 5258' WLM. Increase N2 cushiOn to 2600 psi & gun came loose. Bled N2 cushion to 1500 psi. Reperfed lower part of DST #9 f/ 5508' to 5520' DIL. Pressure increased to 1628 psi in 6 min. Bled off N2 cushion thru 3/8" choke to 22 psi. Shut well in 1 1/2 hrs - pressure increased to 67 psi. POOH w/ WL. RIH w/ 12' perf gun - could not get below 5240' WLM. Charged DP to 1300 psi w/ N2 cushion - still could not get below 5240'. Bled off cushion - gun still Stopped @ 5240'. POOH w/ WL. Filled DP & released pkr. Reverse circ. NOW' Prep to RIH below perfs to circ. LEASE U[1IOIt OIL CCI PA N CALIFOR iIA WELL RECORD FEE LEASE - FREDRICKSON ~I~LL NO, c-~D #3 FIELD St:ELF D PAGE lb. -33 DATE 108 9/10/81 ETD 11125' TD 5493' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 80 PCF 50 SEC DAILY COST' $ 41,164 ACC COST' $5,534,125 AFE AMT' 109 9/1'1/81 DAILY COST' ACC COST: AFE AMT' $5,878,000 1 i'2~' TD )3' ETD (RET) 5/8" C. 8130' L. 11125' to 7783' PCF 47 sEc 39,275 ;5,573,400 ;5,878,000 DE~AILS OF..O.PEPATIOItS, DESCR I PTIQ[!S & .RESULTS RemoVed test manifold & RIH w/ 2 stds of DP to +5540' Circ clean - rec sand (not~: could not rev circ). POOH & LD DST tools. RIH w/ GR & JB to 5530'. POOH. RIH w/ cmt ret on WL & set ret @ 5493' DIL. POOH w/ WL. RIH w/ stab-in tool on DP. Broke circ@ 5490'. Stabbed into ret. Tested surf equip to 4000 psi. Broke down lower DST #9 perfs f/ 5508' to 5520' -"~ DIL w/ 1250 psi. Pump in w/ 4 BPM @ 2000 psi. Form held llO0 psi w/ pumps off 1 min. Mixed & sqz'd w/ 110 sxs cl "G" w/ 2% CaCL2, 8 gal/lO0 sxs R-12L, & 1 gal/lO0 sxs D-6L to ll9 PCF. Dis- pi.aced.85 sxs below ret. w/ a final rate of 4 BPM @ 2800 psi. Sqz held 1750 psi w/ pumps off 1 min. CIP @ 17'25 hrs 9/10/81. Rev out 25 sxs of cmt. POOH w/ DP. RIH w/ DST tools - rabbit DP in hole. NOW- RU test manifold. RU test manifold. Set RTTS pkr @ 5288'. Tested surf equip & lub to 4000 psi. RIH w/ 12' perf gun. Charged DP w/ 1300 psi N2 cushion. Perfed middle portion of DST #9 f/ 5458' to 5470' DIL w/ 2 1/8" enerjet perf guns. Surf pressure increased f/ 1290 psi to 1310 psi in 30 min. POOH w/ WL. RIH w/ 13' gun & perfed upper por- tion of DST #9 f./ 5422'.to 5435' DIL - had no pressure increase. POOH w/ WL. Began to bleed off N2 cushion @ 08'03 hrs. Well began to unload mud @ 08'30 hrs. Flowed well to clean up - put into separator. Had maximum rate of .582 MMCFD @ 275 psi DP pressure. Well was making_+200 BWPD w/ same sand. Cut back on rate. Flowed well until 14:30 hrs. Had final regulated rate of .272 MMCFD @ 148 psi w/ +lO0 BWPD & no sand. Shut well in @ 14' 30 hrs. RIH w/ HP pressure recorder to 5407' DIL. Opened well to fl ow @ 15'30 hrs & fl owed for 2 hrs. Shut well in @ 17'30 hrs. Left well shut in until 24-00 hrs. NOW' Prep to POOH w/ WL. UHIOI.I OIL OF CALI OR :IA RECORD D LFASE FEE LFASE - FREDR_ICKSON HO, #3 FIELD DATE 110 9/12/81 DAILY COST' ACC COST' AFE AMT- 111 9/13/81 DAILY COST' ACC COST' AFE AMT' 112 9/14/81 DAILY COST' ACC COST- AFE AMT' ETD 11125' TD 5300' ETD (RET) 9 5/8" C. 8130' 7" L. 11125' to 7783' 80 PCF 48 SEC $ 54,719 $5,628,119 $5,878,000 11125' TD Surface ETD 9 5/8" C. 8130' 7" L. 11125' to 7783' $ 23,671 $5,651,790 $5,878,000 11125' TD Surface ETD 9 5/8" C. 8130' 7" L. 11125' to 7783' $ 18,800 $5,67O ,590 $5,878,000 DETAILS OF OPEP, ATIOIIS,, DESCRIPTIO.[!S & RESULTS POOH w/ HP pressure recorder - found fluid leveT @ 3350'. Bled off Well ca 02-14 hrs. Put well into separator @ 02'40 hrs. By- passed separator @ 03'30 hrs due to lack of pressure. Had final rate of .09 MMCFD @ 0 psi & 0 BWPD. Released pkr & circ to kill well @ 04'30 hrs. Bullhea'ded 20 bbls of mUd into perfs. RIH w/ 1 std of DP & rev circ - rec sand. Bullheaded 10 bbls - mud. POOH laying down DP & test tools. RIH w/ ret on DP & set ret @ 5300' DPM. Tested surf.equip to 5000 psi. Broke down DST #'9 perfs f/ 5458' to 5470' & 5422' to 5435' DIL w./ 1250 psi. Pumped in w/ 5 BPM @ 2000 psi. Formation held 1150 psi w/ pumps off 1-min. Mixed & sqz'd w/ 150 sxs cl "G" w/ 2% CaC12, 8 gal/lO0 sxs R-12L and 1 gal/lO0 sxs D-6L to 118 PCF. Displaced 132 sxs below ret w/ a final rate of 4 BPM @ 2250 psi. Sqz held 1500 psi w/ pumps off 1 min. CIP @ 20'08 hrs 9/12/81. Rev out 18 sxs cmt. POOH & LD 3 1/2" DP. NOW: Laying down 3 1/2" DP. Continued to POOH laying down DP & DC's. RIH & set cmt ret @ 150'. Removed BOPE. RIH w/ OEDP to 150' & laid in 60 sxs cmt to surface. CIP ca 11:00 hrs 9/13/81. POOH & LD DP. Installed 10" 5M blind flange w/ bleeder valve on top of "DCB" spool. Cleaned mud tanks. LD Kelly. Released rig to move rate @ 24:00 hrs 9/13/81. NOW' Rigging down. Rigging down. Laid derrick down. Cleaned & rigged doWn Swaco FPS unit. Removed & set :aside support bldgs. NOW' Rigging down. · o .. UiiIOi.l OIL Cg?Ath' ~ CALIFOP~iIA ELL S}:EET D PAGE ~b. -35 LEASE FEE LEASE - FREDRICKSON NELL [~0, cm #3 FIELD DATE 113 9/15/81 DAILY COST' ACC COST- AFE AMT' 114 9/16/81 DAILY COST- ACC COST' AFE AMT' ETD 11]25' TD Surface ETD · 9 5/8" C. 8130' 7" L. 11125' to 7783' $ 25,491 $5,696,081 $5,878,000 11125' TD Surface ETD 9 5/8" C. 8130' 7" L. 11125' to 7783' $ 25,500 $5,721,581 $5,878,000 Cont'inued rigging down. Moved Swaco FPS-unit, mat boards, derrick, and substructure to new location. NOW: Moving remainder of rig. Continued rigging down. Moved support buildings and mud products. Moved trailers. Released rig from CLU #3 @ 24'00 hrs 9/16/81. ,~ UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Cannery Loop Unit WELL NO. #3 FIELD Ca_n~er~ Io~ DATE- - - ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS J~S · 2 J~S 67 J~S 2 · ~ 22 10 159 '20" Casing Detail Desc,ription , 20" 94# H-40 Plain. End --' 20" 2000 psi Sow 'Head Top of Head Below K.B. Length Bottcm 53.50' 85.00' 2 00' 31.50' 29.50' 29.50t 13 3/8" CasingDetail Description Length 13 3/8" B&W Float Shoe 1.60' 13 3/8" 61# K-55 Butt. Casing 38.82' , 13 3/8" B&W Stab-In Float Collar 2.17' -13 3/8" 61~ K-55 Butt. Casing 2597.47' ..13 3/8" 61~ K-55 B~tt. Pup 24.24' 20" x 13 3/8" CIWFlutedHanger- 1.80' 20" 2000 psi x 13 5/8"_5000 psi "~" Spool 2.25' Top 31.50 ' 29.50" -0- Bottom 2695.10' 2693.50' 2654.68' 2652.51' 55.04' 3O.8O .. 29.50' Top 2693.50 ' 2654.68 ' 2652.51' 55.04 ' 30.80 ' 29.00' .. 27.25' 9 5/8" Casing Detail Description 9 5/8" B&W Float Shoe 9 5/8" 47~ N-80 Butt. Casing 9 5/8" B&W Float Collar Length Bottcm Top · 1.69' 8130.17' 8128.48' 77.01' 8128.48' 8051.47' 1.67' 8051.47' 8049.80' · 9 5/8" 47~ N-80 ~utt. Casing '862.25' 8049.80' 7187.55' 9 5/8" Butt. Pup 20.14' 7187.55' 7167.41' 91 5/8" 47~ N-80 Butt. Casing 389.06' 7167.41' 6778.35' 9i5/8'' Butt. Pup 15.57' 6778.35' 6762.78' 9 5/8" 47# N-80 Butt. Casing 387.80' 6762.78' 6374.98' 9,.5/8" Butt. Pup 23.16' 6374.98' 6351.82' 9' 5/8" 47# N-80 Butt. casing 6322.38' 6351.82' .. 29.44' 9 5/8" Butt. Cut-off 2.38' 29.44' 27.06' Landed BelowRKB 27.06' 27~06' -0- UNION OIL CO~4°ANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Ca.r~er~ I~o.p Uni~ WELL. NO. #3 FIELD Ca_n. nez~ Zoop DATE ETD DETAILS OF OPERATIONS' DESCRIPTIONS & RESULTS · J~S 1 17 13 13 13 20 Description 7." B.O.T. Float~ Shoe 7" 29# N=80 Butt. Csg. 7" B.O.T. Float Collar 7"' 29~ N-80 Butt. Csg. 7" B.O.T. Catcher Sub .7,, '29#. N-80 Butt. Csg. 7" B.O.T. Landing Sub · 7" 29~, N-80 Butt. Csg. 7" Butt. 'Pup 7" 29# N-80 Butt. Csg. 7" Butt. Pup 7" 29# N-80 Butt. CSg. 7" Butt. Pup 7" 29~. N-80 Butt. Csg. 7" Butt. Pup 7" 29# N-80 Butt. ~Csg. · 7" xo 8rd to Butt. 9 5/8" x 7" B.O.T. Hyd. Hanger 7" Collar w/xo 7" 29# N-80 B~tt. Csg. 7" xo pup B.O.T. 7" Tie !Back'Sleeve i Total Lap - 347' 7" Liner Detail ..~I~.ngth 1.82' 36.45' .96' 42.19' .95' 43.29' .95' 696.06' 10.54' 527.67' 10.31' 540.71' 10.34' 542.23' 10.44' 810.52' .85' 11.13' 1.59' 35.75' 1.17' 6.14' Bottcm 11125.00' 11123.18'i 11086.73' 11085.77' 11043.58, - 11042.63' 10999.34' 10998.'39' 10302.33' · . 10291.79' 9764.12' 9753.81' 9~i3.10' 9202.76' 8660.53' 8650.09' 7839.57' 7838.72 ' 7827.59 ' 7826.00 ' 7790.25 ' 7789.08 ' '11123.18' 11086.73' ., no85 77, 11043.58' 11042.63' 10999.34' 10998.39' 10302.33' 10291.79' 9764.12' 9753.81' ·9213.10' 9202.76' 8660.53' 8650.09' 7839.57' '7838.72' 7827.59' 7826.00' 7790.25' 7789.08' 7782.94' WELL STATUS 1. 9 5/8" cmt ret- 150' w/ cmt to Surface. 2. 9 5/8" cmt ret - 5300' 3. 9 5/8" cmt ret - 5493' 4. Cmt plug f/ 5555' to 5955' 5. 9 5/8" cmt ret - 6050' 6. 9 5/8" cmt ret - 7092' 7. 9 5/8" cmt ret - 7770' 8. 7" cmt ret - 9280' 9. 7" cmt ret - 9775' lO. 7" cmt ret.- 10020' 11. 7" cmt ret - 10391' DATE 10 11 -13 3/8" C. 2695' Top of 7" @ 7783' 5/8" C.. 8130' ETD - 10998' '-- 7" C. 11125' CANNERY LOOP UNIT #3 APP'D. CI(D. ~ FORM 247 (NEW 5/66) Spud' 5/26/81 Suspended- 9/13/81 UNION OIL COMPANY OF CALIFORNIA SHEETS t SHEET Suggested fo].~ to lx i~ertcd in each "Active" well folder to d~.eck for tinmty compliance wi~ our rcx~ulations. - b~x2Jr~tor, Wul'i ~Na~r~ j/nd N~n~r - Date Required Date Received Rcna rks C~npletion ReLort Yes _ -- . ' . Wel 1 Histo~ Yes ~ - , , ~f' ~ "'.~ Core ~scription y~..> / ...... _ Registered Su~ey Plat. y~4. Inclination Su~ey . , 4/d --- ...... - ............ ~[7~ Drill St. Test Re~s ~:S tt {' STATE OF ALASKA ~' MONTHLYALASKA ~ AN DGASCONSERVATION CC(.. ilSSION ~/~ REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ]~] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 81-58 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50-133-20340 4. Location of Well at surface 2790'S & 2440'E of the NW corner, Section 4, T5N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. +62' KB above MSL Fee Lease - Fredrickson 9. Unit or Lease Name CANNERY LOOP UNIT 10. Well No. CANNERY LOOP UNIT #3 11. Field and Pool W I L DCAT For the Month of August ,19__ 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Retrieved fish @ 5468'. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run CBL-VDL-GR-CCL log 7700'-5000' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed: 10530-10534' 10128-10148' 10516-10534' 9902-9915' 10504-10512' 9386-9400' 7194-7202' 7230-7238' 7246-7248' 6091-6093' 5601-5603' 7183-7189' 5832-5834' 5565-5567' 6175-6177' 5779-5781' 5412-5414' 7228-7238' 7192-7202' 6156-6172' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED LE DIST DRLG 'SUPT DATE 9/11181 NOTE--R~'rt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~I~ Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~404 Submit in duplicate Rev. 7-1-80 ~ STATE OF ALASKA ALASKA ~. AND GAS CONSERVATION CC~ ,ISSION MONTHLY REPORT OF DRILLING AND WO___R_KOVER OPERATIONS · Drilling well ~] Workover operation [] 2. Name of operator UNION 0IL COMPANY OF CALIFORNIA 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 so-]33-20340 4. Location of Well at surface 2790'5 & 2440'E Of the NW corner, Section 4, T5N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) +62' KB above HSL 6. Le~se Designation and Serial No. Fee Lease - Fredrickson 9. Unit or Lease Name CANNERY LOOP UNIT 10. Well No. CANNERY LOOP UNIT #3 11. Field and Pool WILDCAT For the Month of JULY ,19 . 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 1652' Footage Drilled 11125' TD 13. Casing or liner run and quantities of cement, results of pressur9 tests 7" L. 11125' to 7783' w/ lO00 sxs cl "G". Tested lap to 5000 psi for 15 min - ok. 14. Coring resume and brief description Cored f/ 10545' to 10575' - 300% recovery. 15. Logs run and depth where run Schlumberger DIL/Sonic w/ SP & GR 10680' VDL/GR lllO' to 7600' FDC/CNL/GR 9370' to 7600' CBL/CCN/Neut/GR 10983' to 2600' SDC Gyro Survey f/ 10980' to 7100'. to 8130' 6 DST data, perforating data, shows of H2S, miscellaneous data Perfed for block squeezes' 9936'-9938' DIL 9898'-9900' DIL 9408'-9410' DIL 9372'-9374' DIL 17. I hereb tify that the foregoing is true and correct to the best of my knowledge· SIGNED AA ~ A ~/TITLE DIST DRLG SUPT DATE 8/18/81 NOTE-/~eyort on this form is required for each calendar month, regardless of the Status of operations, and must be filed in duplicate with the Alaska Oil andl~?.,-~s Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in ;duplicate Rev. 2-1-80 - / STATE OF ALASKA /f" ALASKA ~,~ AND GAS CONSERVATION CO~.,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL E~ COMPLETED WELL [] Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 81-58 OTHER [] 3. Address PO R0X 6247. ANCH01~G_F AK 99502 4. Location of Well 2850'S & 2350'E of NW Corner, Section 4, T5N, RllW, SM. 8. APl Number $o- 133-20340 9. Unit or Lease Name ..j~CANNERY LOOP UNIT 10. Well Number CANNERY LOOP UNIT #3 1 1. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) +50' KB above MSI_ . . 12. 6. Lease Designation and Serial No. FP.e Lease - Fredrick~on Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Stimulate [] Abandon [] Stimulation [] Repair Well [] Change Plans [] Repairs Made [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10`407 with a submitted Form 10-407 for each completion.) Altering Casing I-~ Abandonment [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The 7" casing of Cannery Loop Unit #3 was extended beyond the permitted depth of 7700' to 10850' to the depth of 7785' to 11125'. RECEIVED JUL 2 1 1981 Alaska 0il & Gas Cons. Commission Anchorage Verbal approvaR given by Russ Douglas 7/13/81. 14. I hereb~¥ that the foJ~'~Jng,i~-~l~e aj~d correct to the best of my knowledge. Signed le DIST DRLG SUPT. The s,29Z~.~o~w ?r .C0m mission use Con~4~ns of Ap'p'ro~/al, if any: Date 7/21/..81 By Order of Approved by_ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate jr' STATE Or; ALASKA r ALASKA ~ . AND GAS CONSERVATION CO!. .,IISSION IMO___NT__H_LY REPORT OF DRILLING AND WORKOVER OPERATIC 1. Drilling well J~ Workover operation [] 2. Name of operator UNION OIL COMPANY OF CALIFORNIA Address PO BOX 6247 ANCHORAGE AK 99502 4. Location,of Well atsurface 2790'S & 2451 'E of NW Corner, Section 4, T5N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) +50' KB above MSL 6. Lease Designation and Serial No. Fee Lease 81-5R 8. APl Number 9. Unit or Lease Name CANNERY LOOP UNIT 10. Well No. CANNERY LOOP UNIT 11. Field and Pool WILDCAT For the Month of JUNE ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 6743' Footage Drilled 9473' TD 13. Casing or liner run and quantities of cement, results of pressur9 tests 13 3/8" C. 2695'. Tagged top of cement @ 2624' 9 5/8" C. 8130'. Cemented w/ 750 sxs cl "G". · Tested csg to 2500 psi - ok. Tested csg to 5000 psi - ok. 14. Coring resume and brief description None 15. Logs run and depth whe-re run DIL-Sonic and FDC-CNL-GR log @ 8130'. .1 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED, JUL 1 7 198i Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :SIGN TITLE DIST DRLG StIPT DATE, 7/15/81 NoTE~Report o~ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1:80 Robed T. Anderson District Land Manager Union Oil and Gas/ ;son: Western Region' Union Oil Compan~ _.. California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union J~ne 29, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 - t / 1 /11 3 ENG I -STA:I' TEC CONFER: Atten: Harry W, Kugler Cannery Loop Unit State of Alaska Cannery Loop Unit #3 Well Gentlemen: We are in receipt of your June 16, 1981 letter inquiring as to the status of the two parcels of land which we indicated to you, at our June 9, 1981 meeting, were unleased and within 500 feet of our targets for the subject well. Subsequent to said meeting both of the above mentioned parcels were leased and committed to the Unit thereby eliminating any standoff problems. We enclose herewith for your information a copy of a map showing the location of these previously unleased parcels (Earley Tract #104 and Hilling Tract #121) along with our planned well bore location for subject well. If additional information is needed please contact us. Enclosure Very truly yours, cc: Jim Guild-PLGD - w/encls. Morrie Lowman-Marathon - w/encls. RECEIVEI JUN 3 0 1981 Nasla 011 & Gas Cons. Commlssloe Aflchorage £ STATE OF ALASKA L(:/~ ALASKA ,,LAND GAS CONSERVATION C .~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WE LL)~( COMPLETED WELL [] OTHER [] 2. Name of Operator UNION OIL COMPANY OF 3. Address CALIFORNIA PO BOX 6247 ANCHORAGE AK 99.502 4. Location of Well 2790'S & 2451'E of the NW Corner, Section 4, T5N, RllW, SM 7. Permit N,o. 81-58 8. APl Number 50- ] 33-20340 9, Unit or Lease Name CANNERY LOOP UNIT. 10. Well Number CANNERY LOOP UNIT #3 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) +50' KB Above MSL 6. Lease Designation and Serial No. Fee Lease Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment r~l Repair Well [] Change Plans r-] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The surface location for Cannery Loop Unit #3 well has been corrected as fol.lo~s' FROM' 2850'S. & 2350'E of the NW Corner, Section 4, T5N, RllW, SM. TO' 2790'S & 2451'E of the NW Corner, Section 4, T5N, RllW, SM. (Survey Plat Attached) 14.' h~.~]i~y.~tht~~;,~g is [rue and correct to the best of my knowledge. ohe~ace below for Commission use''~ - .... nditions of Approval, if any: Date 6 / 15/81 Approved by. Form 10-403 COMMISSIONER By Order of the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate N 89- 57- 50W N SCALE 1 "=200' 2650.8 CANNERY LUUP UNIT NO. 3 Well location Y: 2,396,059 X= 208,828 629.13 ,. 200' LEGEND AND NOTES. 1~ [ound officlal survey monument ) Indicates datum of record. All bearings refer to N-S center line of Sec. 4 as shown. Top of well cellar elev.= 35.29 ft. above MSL, based on U.S.G.S. DAIUM. Horizontal locatiOn by AlasKa State Plane Zone 4 ¥= 2,396,069 X= ZSO,SZ8 CANNERY m Reference; City of Kenai map No. G-9, by Walker and Associates, , Inc. LOOP UNIT NO. 3 i ii ii ii i i iii PREPARED FOR UNION OIL COMPANY OF CALIF. OPERATOR u e ii i iml m i i ! i i imll lU m ~UK~ACb LUCAIlON' Z451 t-I.'from the west line and 2490 Fl. from Cne south line in Section 4, TSN, RllW, S.M., Alaska. Surveyed by; McLane and Associates, Inc. Dated; May 27, ]98] i ii ii , i mm ii i ii mi! Ill BK NO. 80- 38 Mr. Robert T. Anderson Dristrict Land Manager Union Oi ! Company of Cali fornia P. O. Box 6247 Anchorage, Alaska 99505 Dear Mr. Anderson A meeting was held on June 9, 1981 in our offices concerning problems with the 1eases in the Cannery Loop Unit. A subse- quent phone ~all indiuated that one of the blocks had. been leased by Union and was no longer a problem. The Commission would like to have a written confirmation that the particular block was leased by Union. Also we would appre- ciate having in our record any change in the planned well bore lo=ation of the Cannery LOOp ~nit No.. 3~e11, the distance the we1! bore wi1! be from unleased land (especially at the expected horizons of pay) and any other particulars that may have a bearing on this matter. Thank you for your help in this matter. Your ~ ye ry truly, Harry W. ~ugler Commissioner STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] Name of Operator Union 0il Company of Calif. 3. Address P,0. BOX 6247, Anch. Ak. 99502 4. Location of Well 2850'S & 2350'E of the N.W. corner, sec. 4, T5N, RllW, S.M. 7. Permit No. 81-58 ~. APl Number 5o- 133-20340 5. Elevation in feet (indicate KB, DF, etc.)----'~ 6. Lease Designation and Serial No. .~ 50' KB above MSL i/Fee lease i2. OTHER [] ____.____------- 9, Unit or Lease Name Canner LDO Unit Well Number ~anner LDO Unit #3 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data SUBSEQUENT REPORT OF: NOTICE OF INTENTION TO: (Submit in Duplicate) (Submit in Triplicate) [~ Altering Casing ~ Perforate [] Alter Casing [] ~ Perforations [~ Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] ' (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting proposed work, for Abandonment see 20 AAC 25.105-170). The 13 3/8" casing point for Cannery Loop Unit #3 was changed from 2500' to 2695'. Verbal Approval from Jim Trimble 5/25/81 that th · tr and correct to the best of my knowledge. Date below for Commission use tions of Approval, if any: Approved by. Form 10,403 Rev. 7-1-80 COMMISSIONER By Order of the Commission Date ~- Submit "Intentions" iD Triplicate and ,'Subsequent Reports" iR DuPlicate ALASK ~ AND GAS CONSERVATION C MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well~[~ Workover operation [] 2. Name of operator UNION OIL COHPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well atsurface 2790'5 & 2440'E of the NN corner, Section 4, TSN, RllN, SR. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. +62 KB above MSL Fee Lease - Fredrickson For the Month of. MAY ' , 19 81 7. Permit No. 81-58 8. APl Number so- 133-20340 9. Unit or Lease Name CANNERY LOOP UNIT 10. Well No. CANNERY LOOP UNIT #3 11. Field and Pool WILDCAT 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date' 5/26/81 Footage Drilled' 2730' Drilled 12 1/4" hole to lO00'. Kicked off at lO00' and directionally drilled 12 1/4" hole' from 1000' to 2730'. Ran logs and opened hole to 17 1/2" f/ 85' to 2120'. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run DIL-Sonic-GR From 2730' to surface. ~ 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED: JUN ! 5 gS! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~lk~,- ~ O,~oe~- 12-I-~C~TITLE gIST DRUG SUPT. DATE 6/9/81 NOTE--Repo{~ on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate AIASKA OIL & GAS OC~SERVATIf~ OOH~ISSIC~ Cha/xmanH°yle H. Hamil~ Lonn~ C. Smith~ Petrole~u Inspector June 10, 1981 Witness B.O.P.E. on Union Oil Co. 's Loop Unit No. 3 Well, Sec. 4, T.5N., R.11W., S.M., Pex~it No. 81-58, on Bri~erhoff Rig. No. 59. Wednesday June 3, 1981: I traveled this date to Kenai to witness the B.O.P.E. Test on Brinkerhoff Rig 59. The test ccmrenced at 4:00 p~. and was co~cl~ at 2:30 p.m. 6-4-81. I filled out an A.O.G.C.C. B.O.P.E. test ~ which is attar. In summazy: I witnessed the B.O.P.E. test cn Union Oil Co. 's Cannery ~ b~t' No. 3. ~ ware t~o failures, which were cozrected and retssted during the course of ~ test. I fi~ cut an A.O.G.C.C. B.O.P.E. test report which is attached. ' O&C #4 4/81 ~, ' STATE OF ALASKA ALASKA OIL & -GAS CONSERVATION CQMMffSSION B .O. P .E. Inspection Report Operator ~1 Weii Location: Sec ~ T~ R}t~ M mil linq mn~a~or Date ~rl~ 9-I~1 , Representative ~,~, ~Casing Set ~ ~9~I ft. Rig ~Repre~ntat ive Location, C~nera] Well Sign.. Ceneral Housekeeping Reserve pit ~:, ok' ACCUMULATOR SYSTEM '~ ' Full Charge Pressure ~~ Pressure After Closure '~ ~-OO .. Pump incr. clos. pres. 200 psig Full charge Pressure Attained: . Controls: Master ~ ~ psig psig psig ~ ~ sec. min47 sec. Remote ~. Blinds switch cover BOPE Stack Annular Preventer Pipe Rams-~ ..~ Blind Rams Choke Line Valves----~__ Test Pressure H.C.R. Valve-- ] Kil 1 Line Valves- ~ Check Valve I Kelly and Floor Safety Valves Upper Kelly Lo~r Kelly_ ~li Type. ._~ Inside BOP Choke Manifold No. Valves No. flanges ...... Adjustable Chokes Hydrauically operated choke Test Pressure Test Pressure Test Pressure Test Pressure ~ Test Pressure Test Results: Failures, '% . Test Tim,' hfs Repair or Replacement of failed equipment to he made within_ days and Inspector/Ccmmission office notified. ........ ,, Distribution orig. - AO&CCC cc - Operator CC - Supervisor Inspector ~ .~..~. April 28, 1981 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O, Box 6247 Anchorage, Alaska 99502 Re: Cannery Loop Unit t3 Onion Oil COmpany of California Permit No. 81-58 Su~. Loc.: 2850~S, 2350~ of NW cr Sec Bo~tomhole Loc.: 1700'$, 800'~ of NE ct, Sec 5, TSN, RI1W, Dear Mr. Anderson: Enclosed is the approved application for permit to drill the above referenced well. Well sam. pies and a mud log are not required. A directional survey is required. If available, a tape contatnint the di§itized log information shall be submitted on all lo§s for copying except experimental logs, velocity surveys and dipmeter aurv:eYs. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Oyerations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Hr, Robert T. Anderson Cannery Loop Unit ~3 -2- April 28, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation, · To aid us tn schedulinE field york, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so thst a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we_may have a vttness present, Very truly yours, Hoyle H. Hauilton ~batrman of BY ORDER O~ ~ CG~.~M~S~ON Enclosure cc: Department of Fish & Game, Habitat Section e/o enCl. Department of Environmental Conservation w/o/encl. Union Oil and Gas~r'' 'son: Western Region Union Oil Compan~of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager April 20, 1981 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 KENAI LOOP AREA 'State of Alaska Cannery Loop Unit ~3 Well Permit to Drill Dear Mr. Hamilton: Enclosed for your approval are three (3) copies of the Permit to Drill Or Deepen (Form.10-401) for the above captioned Wildcat Well. Also enclosed is our check number 19115 in the amount of $100.00 to cover filing fees. Upon approval, we would appreciate an executed copy for our files. sk Enclosures (4) Very truly yours ~erson '-- STATE OF ALASKA ALASKA AND GAS CONSERVATION CO ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~;] lb. Type of well EXPLORATORY'I-)( SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVEL'OPMEN'I:OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE~ ..... 2. Name of operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of well at surface ?850' S' & 2350' E of the NW corner, 9. unit or lease name Section 4, T5N, RllW, SM. Canner.v Loop Unit At top of proposed producing interval 2200'S & 850'E of the NW corner, ~0. We. number Section 4, T5N, R1]W, SM. Cannery Loop Unit #3 11. Field and pool At total depth 1700' S & 800'W of the NE corner, Section 5, T5N, RllW, SM. 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. +50' KB above_. MSLt Fee Lease - Fredrickson Wildcat 12. Bond information (see 20 AAC 25.025) Un-[ted ~acific Tns. Type Statewide Surety and/or number Co~113,qny R-~77 Amount $100,000.00 13. Distance and direction from nearest town 14. Distance to hearest property or lease line 15. Distance to nearest drilling or completed :.5 m%l.es E~s.t.. so~ttheas~,.. 8700' rom'u]_ty cz ~.ena3. .... _. 165, feet well feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 11,350' MD, '10850I TVD feet 96.38 5'~]~;81 '~19. If deviated (see 20 AAC 25.y~O) Y'~20. Anticipated pressures -kw~/UU .psig@~Surface KICK OFF POINT. ,/oo~:~ feet. MAXIMUM HOLE ANGLE.~O ° l (see 20 AAC 25..035 (c) (2) * 5200 .pSig@]0100 ft. TD{TVD) 2~ *Based on test data from CLU #1 **Maximum possible sUrface pressure using weight of Proposed Casing, Liner and Cementing Program gas col umn. SiZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 20" 94# P1 ai n-~ nd +100' urface I +100' ~ Dri yen · 17 1/2 13 3/8 61# K-55 Butt +--2500'" ~ +-2500'1 1400 sx 12 1/4 9 5/8 47# N-80 Butt. +-8200' " ' +-8200'1 1900 sx. 8 1/2 7" 29# N-80 Butt, +3150' +7700' ~ +108501 450 sx. .... I I - 2. Describe proposed program: See attached) APR 2 1 1£ 81 Alaska 0il & Gas Cons. Anch0raga Comm]ssJoa 23. I hereby certify that the _foregoing is true. and correct to the best of my k~owledge SIGNE~~ ~,~C ~_(~TiTLEC~ District Land Mgr, DATE 4/20/81 The space below ¢or Co}nml~sion Use Robel'yT. AI1c~'~so~l ' CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required APl number []YES .~,~O []YES J~[~,O ~YES []NO 50- /j1 ~ -- 'Z, e 3 ~*' O ,, Permit number ~,~ Approval date ~["~) (IA/?R/R1 I SEE COVER LETTER FOR OTHER REQUIREMENITS _ APPROVEDBY ~70--~r--~_~ .~-, ,COMMISSIONER DATE An~'~] i) 91_ ]0911 . -- .r ~ - ..... £ ---- - 7 // ~ ~' ~' by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 Permit to Drill Page 2 · 2. 3. 4. 5. 6. 7. 8. 9. 10. Move in and rig up. Drive 20" conductor to +100'. Drill 12 1/4" vertical hole to +1000'. Drill 12 1/4" directional hole to +2500'. Log and open hole to 17 1/2" to +2500'. Run and cement 13 3/8" casing @ +2500'. Drill 12 1/4" directional hole to +8200'. Run 1 ogs. II ' 't" I Run and cement 9 5/8 casing @ 8200 Drill 8 1/2" directional hole t~+lO,~50' TD. ll. Run logs. 12. Run and cement 7" liner to 10,850' as justified by logs. 13. Test well as required. APR ",:, 1 1<~:,,~I':'' Oil & Gas Cons. Commis$ior~ t~ 2.0" 2. o00 I ' IX 2.o" ,9..ooo ~,sl -I APR 2 I l~3g! Anchor~ t,.. ' ! , i UNibN OIL CC~A,~Y . _ . _ · DEA~¢N _~zS~ _ CKD. . , ....... SHEE~S ~ __ £HECK V.~L YE PIP~ 2ooo es~ 5. o.W. ~OTE ' ALL CHANGES MUST HAVE APPROVAL BT THE DISTRICT DRILLING SUPERINTENDENT · -% , / G.~ TE V.~ L V£ · .g#GLED .FILL UP LI/~ ii ,'~/s" cs5 ~. 9 ~/6" DJOTE ' ALI.. CH3. NGES MUST HAVlg IRRIT.TEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT ii i iiij ! i ii fill 'n /4PR 2 1 lJ~! · i" ~"f' !" DATE -- UNION OIL COMPANY OF C~J. IFORNIA ii i~ iiiii i1[[i i i DRAWN ~ CKD. -- SCALE DATE ii ii i " SHEETS I ~;HF..ET - ii FORM CR-13 1/72 CASING AND TUBING DESIGN CASING ~G CO~ STA~ ~'L,_~-, .,.~ .:~. DA~ z/_. ~ 5'.~. ~ DESIGN BY ~ ~~, ~ ~. II ~)o~,~'/~. mD. GR. II CASING SIZE HOLE SIZE ~ l~. I .~r/~. ~D GR. i INTERVAL LENGTH DESCRiPTiON '~IGHT TENSION 1~[[ b~ ~,f~4 TDF COLLAPSE COLLAPSE CDF W/ BF -top of STREh"G~M PRESS. ~ P£SIST. ,Bottom Top Wt. Grade Thread W/O B~ section TENSION bottom tension lbs lbs 1000 lbs psi_., psi I ' ' BUP~T ?AESSURE YIELD psi BDF PP_~CE PER COS~ Formulae: Collapse resistance in tension X (Collapse p~essure BtLrst Pressure = ~SP + Depth ( Hyd. Gr. II BF (Bouyancy Factor) ~.oo- (o.o~s x ~,~u~ Calculations: ', i 1, area ........ ' Iii ~[o , ~ ~ ~ FED '' I ',Z B<;F, Gr.' 6- 30- 78 7 .. t / ..........~ ! · B.H.L.' lED e± 10,850' · e- + lO,gO0' ;VI · : :.:.:...:...:.:.:~ / j · TARGET ......... 9"?00' ======================= + 9Z50' V0-~ UNION'S PROPOSED ~':':':':':':':':':':':':':"':':':':':+:':':':': ==================================================== DRILLING ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ......... : ....... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ...................... :.:~:.: ........................ ........ . :::::::::::::::::::::::::::::::::::::::::::::::::: .......... :::::~-i: · :' C:A N N ERY LOOP U N IT~ $ :::::::::::::::::::::::::::::::::::::::::::::: -- i: :::.....TARGET A --:::::~:i:!:!:i:!:!:i:i:i:i:!:!:i:!:!:i:!:!:!:!:i:i:.. LUGA ':~-:'"'""""'"'"""""'"'""'"'"""'i' :5500' ' ..................... V SURE LOC. :': :':':':':':':':. F E D, ;':': :':':':':':':': ::::::::::::::::::::::::: :.:.:.:.:.:.:.:-:-:,:-.- :::-:.:.:.:-:.:.:-:-:-.- :,:.:,:.:.:.:,:.:.:,:.:.-.. .................... :.:.:.'.:.:.:.:.:,:.:.CANNERY LOOP UNIT ................... :~:.:.:.:,:.:.:.? ........ .., '::'.'.'.'-'.'.'.','.'.'-'..'.'-' .'.'.'.'-~1.~.:.~.-.?:-~,.~:.:.:...:.:.:.:.:...--....-~.,' '-:-:i" ':'-'.:".'.'.':'-t~ ............... :-8 ::::::::::::::::::::::: :.: :i:i:i:i:i:i:i:i:!:i~:' ' ' ' ......... ':::i~:i:i:i:!:!:!:i:~i':':':':':':':':'":' t:.: .......... ::::::::::::::::::::::::::::::::::::::::::::::::::: .......... ::::::::::::::::::::::::::: ,: ......... :.:. ....... Alaska District PROPOSED WELL LOCATION CANNERY LOOP UNIT N~ .'5 SECTION 5, T 5 N, R II W KEN'Al t" = 2000' OCT. 29, ( CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ITt~4 APPROVE DATE YES NO 1. Is the permit fee attached .......................................... 2. Is ~11 to be located in a dmfined pool ............................. '_~_ 3. Is ~11 located proper distance from property line .................. ~_~ / 4. Is ~11 located proper distance from other ~lls ......... . ........... 5. Is sufficient undedicated acreage available in this pool ............ .~ 6. Is ~11 to be dmviated and is ,=ii ~ore pl~L includod ........... ~... 7. Is operator the only affected p~rty ................................ 8. Can permit be approved before ten-day ~it .......................... (3) Admin ~'-/~-- q'"~'~'"~! 9. (~' thru 11) 10. 11. 12. 13. 14. 15. 16. 17. 18. ,19. 20. 21. 22. 23. 24. (4) 'Ca'sg~'?thru20) (6) Add:~ 25. Does operator haw a bond in force ..... , ..... .. Is'a conservation order needed ...... . · Is adminiStrativ~ approval'needed ................................... Is conductor string provided .............. ............... ' .......... Is enough cen~.nt.used to circuit, re on c.onductor and su.rface ......' .... Will cement tie in surface and intermediate or production strings ...~ Will cement co~r all known productiv~ horizons .................... ~_2~ Will surface casing protect fresh ~ater zones ...................... Will all casing gi~ adequate Safety in collapse, tension and burst.. Is this ~11 to be kicked off from an existing ~llbore ............ ~ Is old wellbo~ akandonm~nt procedtlre included on 10-403., .......... Is adequate w~ll bore separation proposed ........................... Is a di~rter system required ...................................... . ~'~ Are necesSary diagrams of diverter and BOP equipment attached Does BOPE hav~ sufficient pressure rating - Test to __~__o_~E?__ ~si~ . Does the choke manifold comply w/API RP-53 (Feb. 78) ........... Additional requiren~nts ............................................. Additional R~marks: LC%yPZ rev: 03/10/81 INZTZA a O. UNZT O /Orr CU Ss S A OS XO.