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175-022
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,030 feet N/A feet true vertical 10,790 feet 10,860 (fill) feet Effective Depth measured 11,010 feet 10,437 feet true vertical 10,773 feet 10,235 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)2-3/8" 4.6# / L-80 10,455' MD 10,252' TVD Packers and SSSV (type, measured and true vertical depth)AS1-X Ret. Pkr 10,437' MD 10,235' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 0 Water-Bbl MD 80' 3,395' 0 Oil-Bbl measured true vertical Packer 5-1/2"11,028' 9,571' 10,790' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River Field / Hemlock Oil PoolN/A measured TVD Tubing Pressure 1200 Soldotna Creek Unit (SCU) 24A-09 N/A FEDA028997 9,712' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 175-022 50-133-20273-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-120 100 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 140 Authorized Signature with date: Authorized Name: 140 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 80' 3,395' 9,712' 1,509' Conductor Surface Intermediate Production 8,830psi Casing Structural 18" 10-3/4" 7-5/8" Length 6,020psi Collapse 3,400psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 9,190psi 80' 3,395' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:03 am, Apr 28, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.27 14:52:30 -08'00' Taylor Wellman (2143) 4/29/21BJM 7/16/21 RBDMS HEW 4/30/2021 59 SFD 4/28/2021 59 SFD 4/28/2021 SFD 4/28/2021 Failed attempt Rig Start Date End Date E-Line 3/24/21 4/6/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 24A-09 50-133-20273-01-00 175-022 04/06/2021 - Tuesday Crew arrives at facility. Permits, JSA, jobscope. PT 250psi/3,000psi. RIH W/ 5' x 1-11/16'' 0 deg. strip to 8,989', can not pass, work to 9,433'. pick up = 2,100-2,250 pound weight. POOH. RIH W/ GAMMA and CCL and spring knuckle and weight bar only. To 8,930', try to work down, can not pass 8,920' has pick up weight = ~1,650-1,800 pound weight. POOH. OOH rig down, secure well, turn over to production. Crew leaves field. 03/24/2021 - Wednesday Arrive at location, PJSM, permits, jobscope. Begin rig up E-line. PT lubricator 250 psi low/ 3,000 psi high. RIH W/ 1.75'' weight bar for a drift. to ~8,840' cannot pass. POOH. RIH W/ 1.75'' swag cannot pass same spot. POOH. Decide to bring slickline out. Daily Operations: g cannot pass s cannot pass. Unable to reach desired add perf depth. - BJM can not pass, can not pass 8,920' ___________________________________________________________________________________ Updated by DMA 04-08-13 SCHEMATIC Soldotna Creek Unit Well: SCU 24A-09 Completion Date: 02/04/13 PTD: 175-022 API: 50-133-20273-00 Tag fill @ 10,860’ on 2/3/2013 CASING DETAIL Size Wt Grade Conn Top Bottom 18” 104 Surf 80' 10-3/4” 40.5 K-55 Butt Surf 3,395' 7-5/8” 33.7 P-110 Butt Surf 60’ 26.4 N-80 Butt 60’ 4,137' 29.7 N-80 8rd LT&C 4,137' 6,061' 33.7 P-110 8rd LT&C 6,061’ 9,712’ 5-1/2” 20 N-80 N-80 9,519' 11,028' TUBING DETAIL 2-3/8” 4.6 L-80 EUE Surf 10,455' 7-5/8” Stage Collar @ 7,869’ JEWELRY DETAIL No. Depth ID OD Item 1 15’ - - Tubing Hanger, Shaffer, 2-3/8 CIW BPVP 2 2,291’ 1.901 4.25 GLM 8rd, BK-2 Latch Mandrel 3 3,994’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 4 5,282’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 5 6,381’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 6 7,297’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 7 8,081’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 8 8,862’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 9 9,461’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 10 9,953’ 1.901 3.75 GLM 8rd T-1 Latch Mandrel 11 10,384’ 1.901 3.75 GLM 8rd T-1 Latch Mandrel, Orifice 12 10,435’ 1.875 4.5 On/off tool w/ X Profile 13 10,437’ 1.940 4.625 AS1-X Ret. Packer 14 10,450’ 1.791 3 XN Landing Nipple 15 10,455’ 2 3 WLEG TD = 11,030’ MD; 10,790’ TVD / PBTD = 11,010’MD; 10,773’ TVD Hole Angle = 25q/ KOP=7,000’ ’ PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date Detail G 10,564’ 10,590’ 10,354’ 10,379’ 26 6 3/28/01 2-1/2” PJ 10,610’ 10,620’ 10,397’ 10,407’ 10 6 3/28/01 2-1/2” PJ H-1 10,627’ 10,645’ 10,413’ 10,430’ 18 6 7/11/97 2-1/8” Enerjet 10,629' 10,647' 10,415' 10,432' 18 6 2/4/13 3-3/8" HC Guns H-2 10,659' 10,685' 10,443' 10,468' 26 6 Future 3-3/8" HC Guns 10,660’ 10,687’ 10,444’ 10,470’ 27 6 7/11/97 2-1/8” Enerjet H-3 10,693' 10,724' 10,475' 10,504' 31 6 2/4/13 3-3/8" HC Guns 10,695’ 10,737’ 10,477’ 10,517’ 42 6 7/11/97 2-1/8” Enerjet H-8 10,819' 10,852' 10,594’ 10,625’ 33 6 2/3/13 3-3/8" HC Guns Hemlock 10,822' 10,835' 10,596' 10,609' 13 4 9/13/1975 Hemlock 10,845' 10,884' 10,618' 10,655' 39 4 9/13/1975 Hemlock 10,894' 10,910' 10,664' 10,679' 16 4 9/13/1975 RKB to TBG Hanger = 15.00’ Cameron 3” Type “H” BPV 2 1 4 5 6 DV @ 7,869’ 7 8 9 10 11 13 14 15 3 18” 10-3/4” 7-5/8” 5-1/2” H1 H2 H3 H8 Hemlock 12 G XN Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/12/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 24A-09 (PTD 175-022) DRIFT / DUMMY RUN 03/24/2021 Please include current contact information if different from above. PTD: 1750220 E-Set: 34956 Received by the AOGCC 04/12/2021 04/12/2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,030'10,860' (fill) Casing Collapse Structural Conductor Surface 1,580psi Intermediate 3,400psi Production 8,830psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng todd.sidoti@hilcorp.com 10,790'11,010'10,773'2,157 N/A AS1-X Retrievable Packer; N/A 10,437' MD / 10,235' TVD; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028997 175-022 50-133-20273-00-00 Soldotna Creek Unit (SCU) 24A-09 Swanson River Field / Hemlock Oil Pool Length Size CO 123B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 4.6# / L-80 TVD Burst 10,455' 9,190psi MD 6,020psi 3,310psi 80' 3,395' 9,571' 80' 3,395' 10,790'5-1/2" 18" 10-3/4" 80' 7-5/8"9,712' 3,395' 11,028' Perforation Depth MD (ft): 9,712' See Attached Schematic 1,509' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: March 22, 2021 2-3/8" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:34 am, Mar 10, 2021 321-120 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.09 22:05:55 -09'00' Taylor Wellman (2143) BJM 3/16/21 DSR-3/10/21SFD 3/10/2021 10-404 Comm 3/16/21 dts 3/16/2021 JLC 3/16/2021 RBDMS HEW 3/17/2021 Well Prognosis Well: SCU 24A-09 Date: 3/8/2021 Well Name: SCU 24A-09 API Number: 50-133-20273-00-00 Current Status: Oil Producer Leg: N/A Estimated Start Date: 3/22/2021 Rig: E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-022 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: 212-00275 Max. Expected BHP: 3220 psi @ 10,630’ TVD (Based on Hemlock Gradient) Max. Anticipated Surface Pressure: 2157 psi (BHP - 0.1 psi/ft gas gradient to surface) Brief Well Summary SCU 24A-09 is a vertical well sidetracked from SCU 24-09 in May 1975. After a variety of drilling complications (union strike and plugging back to redrill around stuck pipe), it was finally brought online, initially flowing 2500+ BOPD from the H-7 bench. Oil rate steadily declined over the next 15 years, ultimately bottoming out at ~200 BOPD and 2.1MMBO cum produced when the well was SI in early 1990. Following a workover to remove and reduce fill, SCU 24A-09 came back online in February 1994 with rates hovering around 200 BOPD for the next three years. Water in the H-7 eventually increased, swamping oil until it fell to ~30 BOPD. In July 1997, the H-1, H-2, and H-3 were shot, but did not improve production. In March 2001, the G2 was shot, also without effect. By September 2001, oil died completely and the well was SI. After more than a decade offline, the H-1 and H-3 benches were reshot in February 2013, along with new perfs in the H-7. These zones brought in barely 10 BOPD and 300 BWPD, but were intermittently produced until November 2019. Since then, SCU 24A-09 has remained SI yet with functional surface kit. Recent review of the logs shows some promise in the G1 and the H-5 benches. That review has also revealed bypassed gas in the Tyonek 68-0 sand. Before abandoning the lower wellbore to develop this prospective gas, the team first wants to pursue low-cost, end-of-life Hemlock and Tyonek oil perf adds. E-line Procedure 1. MIRU E-line. Pressure test lubricator to 250 psi low / 3000 psi high. 2. Perforate per the table below with 1-3/4” Razor HSD guns loaded at 6 SPF. a. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Meredyth Richards), and Geologist (Jeff Nelson) for confirmation. Sand TOP MD BOT MD Total TOP TVD BOT TVD Pool Order to Shoot Tyonek G1 10475 10497 22 10271 10291 SRU Hemlock / G 1 H5 10744 10795 51 10526 10571 SRU Hemlock / G 2 3. POOH. RD E-line. 4. Turn well over to production. Attachments: Current Schematic, Proposed Schematic ___________________________________________________________________________________ Updated by DMA 04-08-13 SCHEMATIC Soldotna Creek Unit Well: SCU 24A-09 Completion Date: 02/04/13 PTD: 175-022 API: 50-133-20273-00 Tag fill @ 10,860’ on 2/3/2013 CASING DETAIL Size Wt Grad e Conn Top Bottom 18” 104 Surf 80' 10-3/4” 40.5 K-55 Butt Surf 3,395' 7-5/8” 33.7 P-110 Butt Surf 60’ 26.4 N-80 Butt 60’ 4,137' 29.7 N-80 8rd LT&C 4,137' 6,061' 33.7 P-110 8rd LT&C 6,061’ 9,712’ 5-1/2” 20 N-80 N-80 9,519' 11,028' TUBING DETAIL 2-3/8” 4.6 L-80 EUE Surf 10,455' 7-5/8” Stage Collar @ 7,869’ JEWELRY DETAIL No. Depth ID OD Item 1 15’ - - Tubing Hanger, Shaffer, 2-3/8 CIW BPVP 2 2,291’ 1.901 4.25 GLM 8rd, BK-2 Latch Mandrel 3 3,994’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 4 5,282’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 5 6,381’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 6 7,297’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 7 8,081’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 8 8,862’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 9 9,461’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 10 9,953’ 1.901 3.75 GLM 8rd T-1 Latch Mandrel 11 10,384’ 1.901 3.75 GLM 8rd T-1 Latch Mandrel, Orifice 12 10,435’ 1.875 4.5 On/off tool w/ X Profile 13 10,437’ 1.940 4.625 AS1-X Ret. Packer 14 10,450’ 1.791 3 XN Landing Nipple 15 10,455’ 2 3 WLEG TD = 11,030’ MD; 10,790’ TVD / PBTD = 11,010’MD; 10,773’ TVD Hole Angle = 25q/ KOP=7,000’ ’ PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date Detail G 10,564’ 10,590’ 10,354’ 10,379’ 26 6 3/28/01 2-1/2” PJ 10,610’ 10,620’ 10,397’ 10,407’ 10 6 3/28/01 2-1/2” PJ H-1 10,627’ 10,645’ 10,413’ 10,430’ 18 6 7/11/97 2-1/8” Enerjet 10,629' 10,647' 10,415' 10,432' 18 6 2/4/13 3-3/8" HC Guns H-2 10,659' 10,685' 10,443' 10,468' 26 6 Future 3-3/8" HC Guns 10,660’ 10,687’ 10,444’ 10,470’ 27 6 7/11/97 2-1/8” Enerjet H-3 10,693' 10,724' 10,475' 10,504' 31 6 2/4/13 3-3/8" HC Guns 10,695’ 10,737’ 10,477’ 10,517’ 42 6 7/11/97 2-1/8” Enerjet H-8 10,819' 10,852' 10,594’ 10,625’ 33 6 2/3/13 3-3/8" HC Guns Hemlock 10,822' 10,835' 10,596' 10,609' 13 4 9/13/1975 Hemlock 10,845' 10,884' 10,618' 10,655' 39 4 9/13/1975 Hemlock 10,894' 10,910' 10,664' 10,679' 16 4 9/13/1975 RKB to TBG Hanger = 15.00’ Cameron 3” Type “H” BPV 2 1 4 5 6 DV @ 7,869’ 7 8 9 10 11 13 14 15 3 18” 10-3/4” 7-5/8” 5-1/2” H1 H2 H3 H8 Hemlock 12 G XN Future ___________________________________________________________________________________ Updated by TCS 03-08-21 PROPOSED SCHEMATIC Soldotna Creek Unit Well: SCU 24A-09 Completion Date: 02/04/13 PTD: 175-022 API: 50-133-20273-00 Tag fill @ 10,860’ on 2/3/2013 CASING DETAIL Size Wt Grade Conn Top Bottom 18” 104 Surf 80' 10-3/4” 40.5 K-55 Butt Surf 3,395' 7-5/8” 33.7 P-110 Butt Surf 60’ 26.4 N-80 Butt 60’ 4,137' 29.7 N-80 8rd LT&C 4,137' 6,061' 33.7 P-110 8rd LT&C 6,061’ 9,712’ 5-1/2” 20 N-80 N-80 9,519' 11,028' TUBING DETAIL 2-3/8” 4.6 L-80 EUE Surf 10,455' 7-5/8” Stage Collar @ 7,869’ JEWELRY DETAIL No. Depth ID OD Item 1 15’ - - Tubing Hanger, Shaffer, 2-3/8 CIW BPVP 2 2,291’ 1.901 4.25 GLM 8rd, BK-2 Latch Mandrel 3 3,994’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 4 5,282’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 5 6,381’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 6 7,297’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 7 8,081’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 8 8,862’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 9 9,461’ 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 10 9,953’ 1.901 3.75 GLM 8rd T-1 Latch Mandrel 11 10,384’ 1.901 3.75 GLM 8rd T-1 Latch Mandrel, Orifice 12 10,435’ 1.875 4.5 On/off tool w/ X Profile 13 10,437’ 1.940 4.625 AS1-X Ret. Packer 14 10,450’ 1.791 3 XN Landing Nipple 15 10,455’ 2 3 WLEG TD = 11,030’ MD; 10,790’ TVD / PBTD = 11,010’MD; 10,773’ TVD Hole Angle = 25q/ KOP=7,000’ ’ PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date Detail G1 ~10,475’ ~10,497’ ~10,271’ ~10,291’ ~22 6 - 1.75” Razor G2 10,564’ 10,590’ 10,354’ 10,379’ 26 6 3/28/01 2-1/2” PJ 10,610’ 10,620’ 10,397’ 10,407’ 10 6 3/28/01 2-1/2” PJ H-1 10,627’ 10,645’ 10,413’ 10,430’ 18 6 7/11/97 2-1/8” Enerjet 10,629' 10,647' 10,415' 10,432' 18 6 2/4/13 3-3/8" HC Guns H-2 10,659' 10,685' 10,443' 10,468' 26 6 Future 3-3/8" HC Guns 10,660’ 10,687’ 10,444’ 10,470’ 27 6 7/11/97 2-1/8” Enerjet H-3 10,693' 10,724' 10,475' 10,504' 31 6 2/4/13 3-3/8" HC Guns 10,695’ 10,737’ 10,477’ 10,517’ 42 6 7/11/97 2-1/8” Enerjet H-5 ~10,744’ ~10,797’ ~10,526’ ~10,571’ ~53 6 - 1.75” Razor H-8 10,819' 10,852' 10,594’ 10,625’ 33 6 2/3/13 3-3/8" HC Guns Hemlock 10,822' 10,835' 10,596' 10,609' 13 4 9/13/1975 Hemlock 10,845' 10,884' 10,618' 10,655' 39 4 9/13/1975 Hemlock 10,894' 10,910' 10,664' 10,679' 16 4 9/13/1975 RKB to TBG Hanger = 15.00’ Cameron 3” Type “H” BPV 2 1 4 5 6 DV @ 7,869’ 7 8 9 10 11 13 14 15 3 18” 10-3/4” 7-5/8” 5-1/2” H1 H2 H3 H8 Hemlock 12 G1 XN G2 H5 Future STATE OF ALASKA AL7�SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RE 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing Lf DEC pelt?shutdown U Performed: Suspend ❑ N4 Perforate 0Other Stimulate ElAlter Casing ElChange Approved Program ❑ Plug for Redrill ❑ arfocate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ OtheA ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drilc Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 175-022 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-133-20273-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028997 Soldotna Creek Unit(SCU)24A-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: /6/ / Q /44— �i ,(/'„> L Total Depth measured 11,030 feet Plugs // measured N/A feet true vertical 10,790 feet Junk measured 10,860(fill) feet �� .../44,,. Effective Depth measured 10,860 feet Packer measured 10,437 feet ` true vertical 10,632 feet true vertical 10,235 feet ,l 4.--6-/ Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 18' 80' 80' Surface 3,395' 10-3/4” 3,395' 3,395' 3,310 psi 1,580 psi Intermediate 9,712' 7-5/8" 9,712' 9,571' 6,020 psi 3,400 psi Production 1,509' 5-1/2" 11,028' 10,790' 9,190 psi 8,830 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#/L-80 10,455'MD 10,252'TVD Packers and SSSV(type,measured and true vertical depth) AS1-X Ret.Pkr 10,437'MD 10,235'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A C Treatment descriptions including volumes used and final pressure: N/A SCANNED JAN 1 9 18 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 140 140 Subsequent to operation: 0 0 0 1000 970 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 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: 317-488 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer hilcoro.com Authorized Signature: �/L _ Date: [a."24,(i7 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 A 11//1 RE:'" (,-i : ' ' rr ° Submit Original Only II • •Soldotna Creek Unit Well: SCU 24A-09 SCHEMATIC Completion Date: 02/04/13 PTD: 175-022 Hilcarp Alaska,LLC API: 50-133-20273-00 RKB to TBG Hanger=15.00' Cameron 3"Type"H" BPV CASING DETAIL 1 Size Wt Grade Conn Top Bottom 18" 104 Surf 80' 18 L , 10-3/4" 40.5 K-55 Butt Surf 3,395' 33.7 P-110 Butt Surf 60' 7-5/8" 26.4 N-80 Butt 60' 4,137' P 2 29.7 N-80 8rd LT&C 4,137' 6,061' 33.7 P-110 8rd LT&C 6,061' 9,712' 5-1/2" 20 N-80 N-80 9,519' 11,028' 10-3/4" L , TUBING DETAIL 3 2-3/8" 4.6 L-80 EUE Surf 10,455' 7-5/8"Stage Collar @ 7,869' CM 4 JEWELRY DETAIL No. Depth ID OD Item 1 _ 15' - - Tubing Hanger,Shaffer,2-3/8 CIW BPVP 5 2 2,291' 1.901 4.25 GLM 8rd,BK-2 Latch Mandrel 3 3,994' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 4 5,282' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 5 6,381' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 6 7,297' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel k j 6 7 8,081' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 8 8,862' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 9 9,461' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 10 9,953' 1.901 3.75 GLM 8rd T-1 Latch Mandrel DV @ 7,869' Z , 11 10,384' 1.901 3.75 GLM 8rd T-1 Latch Mandrel,Orifice 7 12 10,435' 1.875 4.5 On/off tool w/X Profile 13 10,437' 1.940 4.625 AS1-X Ret.Packer 14 10,450' 1.791 3 XN Landing Nipple 15 10,455' 2 3 WLEG 08 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date Detail ii 9 10,564' 10,590' 10,354' 10,379' 26 6 3/28/01 2-1/2"P.I G 10,610' 10,620' 10,397' 10,407' 10 6 3/28/01 2-1/2"PJ 7-5/8,. 2M/ 10,627' 10,645' 10,413' 10,430' 18 6 7/11/97 2-1/8"Enerjet 10 H-1 10,629' 10,647' 10,415' 10,432' 18 6 2/4/13 3-3/8"HC Guns 11 10,659' 10,685' 10,443' 10,468' 26 6 Future 3-3/8"HC Guns ii 12 H 2 10,660' 10,687' 10,444' 10,470' 27 6 7/11/97 2-1/8"Enerjet s 13 10,693' 10,724' 10,475' 10,504' 31 6 2/4/13 3-3/8"HC Guns TB 14 H-3 10,695' 10,737' 10,477' 10,517' 42 6 7/11/97 2-1/8"Enerjet - H-8 10,819' 10,852' 10,594' 10,625' 33 6 2/3/13 3-3/8"HC Guns G = 15 H1 - Hemlock 10,822' 10,835' 10,596' 10,609' 13 4 9/13/1975 H2 - Hemlock 10,845' 10,884' 10,618' 10,655' 39 4 9/13/1975 H3 = Hemlock 10,894' 10,910' 10,664' 10,679' 16 4 9/13/1975 H8 Hemlock =-- ft..-..r`m """ Tag fill @ 10,860'on 2/3/2013 5-1/2" rl'rosh s zife a: TD=11,030'MD;10,790'TVD/PBTD=11,010'MD;10,773'TVD Hole Angle=25°/KOP=7,000' Updated by DMA 04-08-13 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 24A-09 E-Line/SL 50-133-20273-01 175-022 10/25/17 10/29/17 Dail .O erations 10/25/2017-Wednesday Sign in. Mobe to location. PTW and JSA. Rig up lubricator. Check tools and CCL/GR didn't check out.Trouble shoot tool string. Found problem with CCL/GR and fixed. PT lubricator to 250 psi low and 2,500 psi high. Found problem with detonators while arming gun. Engineer made some calls fixed detonator problem. Armed gun.TP- 147 psi. RIH w/ 1- 11/16" x 10'Tri-strip gun, 6 spf,45 deg phase and gun set down at 8,930' KB.Tried 4 times to get past obstruction but f could not. Gun was setting down approx. 68' below a GLM. Started out of hole with perf gun and was pulling about 350 lbs over tool wt. Lost 200 lb of line drag at 8,670', another 100 lbs at 8,250' and about 100 lbs at 7,910'. Out of hole found what looks like asphaltenes on gun and tools. Call town. Rig down E-line equipment and move to SRU 241- 33. Slickline will be out in the AM. 10/27/2017- Friday Arrive @ Swanson. Perform JSA,gain permit approval. Depart for Pad. Begin stand Up. Perform PT to 2,500#,test good. RIH w/5' 1-3/4 DD bailer to 8,600' KB w/t to 9,220' KB w/t 9,840' KB w/t 10,880' KB. POOH. Standby for pumping. Rig up to well, PT 1,200 psi. Bring on 12 bbls xylene, standby for vac truck to bring 23 bbls crude.Vac truck arrives, begin pumping xylene down tubing. Finish pumping xylene, begin pumping crude down tubing. RIH w/ 1.79" brush to 8,780' KB w/t to 10,480' KB. Make multiple passes. POOH. RIH w/20' 1-3/4" dummy gun to 8,940' KB w/t, 1It,. cannot pass. POOH. RIH w/8' 1-3/4" dummy gun without knuckle joint to 8,940' KB w/t, cannot pass. POOH. RIH w/8' 1-3/4 dummy gun with knuckle joint to 8,940' KB w/t, cannot pass. POOH. Rig down lubricator and hot oiler.Turn well over to field. 10/28/2017-Saturday Arrive @ office. PJSM and review JSA. Fetch S/L unit. Inspect location and rig up .125". Discuss on how to configure toolstring to match E-line tools. R/U slickline .125". PIT to 2,500 psi, pass. RIH w/5' 1.75" DD bailer. No issues to 10,876' KB. 5'x 1.75" bailer, 1-11/16" x 5' stem, 1-11/16" KJ, spangs,jars, 1-1/2" x 5' stem. OOH/bailer. RIH w/ 10' 1.75" DD bailer. S/D 100' minute @ 8,576' KB. P/U and try again @ 150' and pass without issue. S/D again 8,978' KB. Pick up and try again @ 180' minute. No issue Just added 5'to bailer. Drift and tag 10,875' KB. Rig down slickline and rig up E-line. PT to 250 psi low and 2,500 psi high. RIH w/ 1-11/16" x s10'Tri strip gun, 6 spf, CCL/GR, 1-11/16" E-line KJ, 1-11/16" x 7' wt bar and tie into SLB RST log. Set down in GLM at 8,081'. Work gun thru and went on down to 8,954'.Tried different speeds to get gun to fall thru. Gun would not fall thru tight spot. POOH. Gun was not bent. Had some worn spots on it. Called and discussed with town. Will have one 5' gun built and see if it will go down. Tools did not have any asphaltenes on them. They were clean. It acts like a length /friction problem. Halliburton will have a gun built and be back out at 10:30 in the morning. Rig down lubricator and secure well. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 24A-09 E-Line/SL 50-133-20273-01 175-022 10/25/17 10/29/17 Daily Operations: " 73x 10/29/2017 Sunday Sign in at office. Mobe to location. PTW and JSA. PT 250 psi low and 2,500 psi high.TP 250 psi. Halliburton gun loader had to load build gun this morning. RIH with 1-11/16" x 5'Tri strip gun, 6 spf and tie into SLB RST log.Tools set down at 8,954'.Tried numerous times to get by but could not.Tool had very little over pull. POOH.Tools clean. Going to add 1-11/16" x 7' wt and and another 1-11/16" KJ and try again.Tool string 28' long. Slickline ran a dummy gun set up pretty close to this set up yesterday and had no problem getting down. RIH with 1-11/16" x 5'Tri strip gun, 6 spf and tie into SLB RST log.Tools set down at 8,993'. Had 300 to 400 lbs over pull up to 8,954' and then be at normal weight. Tried numerous times at different speeds with same results. POOH and tools didn't have anything on them. Looked clean and couldn't really tell on the tools if there were wore spots.Tool string 35' long. Rig down lubricator and secure well. Release Halliburton while decision was made on what to do next. • • 1111 OF Tits \�\ I�js THE STATE Alaska Oil and Gas 41 --���� OfALASKA Conservation Commission '. s = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1 `*h' Main: 907.279.1433 ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC SCANNED DEC 0 82017, 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 24A-09 Permit to Drill Number: 175-022 Sundry Number: 317-488 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of October, 2017. RBD,73 5 2617 , RECEIVED • • STATE OF ALASKA OCT 1 1 291? ALASKA OIL AND GAS CONSERVATION COMMISSION I /S /0// /(/ APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend El Perforate Q - Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q• 175-022 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20273-00' 7.If perforating: /.Z 4, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO�-3'k ,/f.,1 y,t7 Soldotna Creek Unit(SCU)24A-09 • Will planned perforations require a spacing exception? Yes 1:1 No No 2 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 • Swanson River Field/Hemlock Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,030' • 10,790' ' 11,010' 10,773' —700 psi N/A 10,860'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 18" 80' 80' Surface 3,395' 10-3/4" 3,395' 3,395' 3,310 psi 1,580 psi Intermediate 9,712' 7-5/8" 9,712' 9,571' 6,020 psi 3,400 psi Production 1,509' 5-1/2" 11,028 10,790' 9,190 psi 8,830 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6#/L-80 10,455' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): AS1-X Ret.Pkr;N/A 10,437'MD/10,235'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development❑r • Service 0 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: October 24,2017 OIL ❑ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com Contact Phone: 777-8420 Authorized Signature: ��� Date: 10/10/!7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 11 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: ! 0.- Li oil APPROVED BY 1� `}(+� Approved by: COMMISSIO�EF I IHS CSO VII SIGN �//�/D,aate/ to-g-17 o RINA /�//t rZ i7 6Pc `� S mit Form and \rNFptm'10-403 evised 4/2017 proved application is valid for 12 months from the date of approval. Attachments in Duplicate tv' \ - • • • Well Prognosis Well: SCU 24A-09 Hileorp Alaska,LLQ Date: 10/11/2017 Well Name: SCU 24A-09 API Number: 50-133-20273-00 Current Status: Shut in Oil Producer • Leg: N/A Estimated Start Date: October 25, 2017 Rig: E-line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz Permit to Drill Number: 175-022 First Call Engineer: Ted Kramer (907)777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 AFE Number: Current Bottom Hole Pressure: —2,200 psi @ 10,386' TVD (From Static log ran on 10/9/17) Maximum Expected BHP: 4,550 psi @ 10,405' TVD Calc. using a 0.437 gradient Max. Potential Surface Pressure: —700 psi (Based on a full oil column of 34 API oil) Brief Well Summary Soldotna Creek Unit 24A-9 was drilled in 1977 to develop oil reserves in the H-8 sand lobe. The original hole was junked with a drill pipe fish and the well was sidetracked(24A-09). The original completion was in the lower H-8. A plug was set in the nipple above the lowest set of perfs and opened the sliding sleeves to produce the upper intervals. The well flowed until 1990. Unocal worked over the tubing in 1993, leaving the original completion in the well and recompleted shallower until 1997. The well was worked over in 1997 which added perforations in the upper hemlock. In 2013 Hilcorp worked over the well removing several isolation packers and re-perforating several Hemlock intervals.. The purpose of this sundry is to add the H-5 perforations which have not been perforated in this well. • Notes Regarding Wellbore Condition • Well current well status is shut in oil well but is occasionally produced to recover some flush production. Brief Procedure: 1. MIRU e-line unit. Pressure Test lubricator to 2,500 psi. 2. PU and RIH with perf Guns. Log on depth and perforate the following interval. Zone Sands Top (MD) Btm (MD) FT Hemlock H-5 ±10745' ±10,785' 40' a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Gamma/CCL correlation log. e. Install Crystal gauges before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Hemlock&Tyonek G Pool based on Conservation Order No. 123A. 3. RD E-line. 4. Turn Well over to Production. • • • Well Prognosis Well: SCU 24A-09 Hilcorp Alaska,LLQ Date:10/11/2017 Attachments: 1. As-built Schematic 2. Proposed Schematic H . •oldotna Creek Unit Well: SCU 24A-09 SCHEMATIC Completion Date: 02/04/13 PTD: 175-022 Ililcora Alaska,LLC API: 50-133-20273-00 RKB to TBG Hanger=15.00' Cameron 3"Type"H" BPV CASING DETAIL 1 Size Wt Grade Conn Top Bottom 18" 104 Surf 80' 18" L , 10-3/4" 40.5 K-55 Butt Surf 3,395' 33.7 P-110 Butt Surf 60' 7-5/8" 26.4 N-80 Butt 60' 4,137' (• .02 29.7 N-80 8rd LT&C 4,137' 6,061' 33.7 P-110 8rd LT&C 6,061' 9,712' 5-1/2" 20 N-80 N-80 9,519' 11,028' 10-3/4" L , TUBING DETAIL 3 2-3/8" 4.6 L-80 EUE Surf 10,455' 7-5/8"Stage Collar @ 7,869' I IV 4 JEWELRY DETAIL No. Depth ID OD Item 1 15' - - Tubing Hanger,Shaffer,2-3/8 CIW BPVP 5 2 2,291' 1.901 4.25 GLM 8rd,BK-2 Latch Mandrel 3 3,994' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 4 5,282' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 5 6,381' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 6 7,297' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel i l 6 7 8,081' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 8 8,862' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 9 9,461' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 10 9,953' 1.901 3.75 GLM 8rd T-1 Latch Mandrel DV @ 7,869' L , 11 10,384' 1.901 3.75 GLM 8rd T-1 Latch Mandrel,Orifice L. d 7 12 10,435' 1.875 4.5 On/off tool w/X Profile 13 10,437' 1.940 4.625 AS1-X Ret.Packer 14 10,450' 1.791 3 XN Landing Nipple 15 10,455' 2 3 WLEG I Bs PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date Detail ' ' 9 10,564'. 10,590' 10,354' 10,379' 26 6 3/28/01 2-1/2"PJ G 10,610' • 10,620' 10,397' 10,407' 10 6 3/28/01 2-1/2"Pi 7-5/8" r =I 10,627'• 10,645' 10,413' 10,430' 18 6 7/11/97 2-1/8"Enerjet dr 10 H-1 10,629'4 10,647' 10,415' 10,432' 18 6 2/4/13 3-3/8"HC Guns i 11 10,659' • 10,685' 10,443' 10,468' 26 6 Future 3-3/8"HC Guns II H-2 t211' 12 10,660' • 10,687' 10,444' 10,470' 27 6 7/11/97 2-1/8"Enerjet " "mg' 13 10,693' . 10,724' 10,475' 10,504' 31 6 2/4/13 3-3/8"HC Guns 14 H-3 10,695' 10,737' 10,477' 10,517' 42 6 7/11/97 2-1/8"Enerjet H-8 10,819' 10,852' 10,594' 10,625' 33 6 2/3/13 3-3/8"HC Guns G - 15 H1 - Hemlock 10,822'• 10,835' 10,596' 10,609' 13 4 9/13/1975 H2 = Hemlock 10,845'• 10,884' 10,618' 10,655' 39 4 9/13/1975 H3 = Hemlock 10,894' - 10,910' 10,664' 10,679' 16 4 9/13/1975 H8 Hemlock - Tag fill @ 10,860'on 2/3/2013 5-1/2" L4,' r2 ....V ,:I. TO=11,030'MD;10,790'ND/PBTD=11,010'MD;10,773'ND Hole Angle=25°/KOP=7,000' Updated by DMA 04-08-13 ‘ 113 0 • Soldotna Creek Unit Well: SCU 24A-09 PROPOSED SCHEMATIC Completion Date: 02/04/13 PTD: 175-022 Hilcorp Alaska,LLC API: 50-133-20273-00 RKB to TBG Hanger= 15.00' Cameron 3"Type "H" BPV CASING DETAIL Size Wt Grade Conn Top Bottom 18" 104 Surf 80' 1 10-3/4" 40.5 K-55 Butt Surf 3,395' 18"L , 33.7 P-110 Butt Surf 60' 7-5/8" 26.4 N-80 Butt 60' 4,137' 29.7 N-80 8rd LT&C 4,137' 6,061' 33.7 P-110 8rd LT&C 6,061' 9,712' iiii 6 2 5-1/2" 20 N-80 N-80 9,519' 11,028' TUBING DETAIL 10-3/4" L , 2-3/8" 4.6 L-80 EUE Surf 10,455' 7-5/8"Stage Collar @ 7,869' t3 JEWELRY DETAIL No. Depth ID OD Item 4 1 15' - - Tubing Hanger,Shaffer,2-3/8 CIW BPVP 2 2,291' 1.901 4.25 GLM 8rd,BK-2 Latch Mandrel 3 3,994' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 4 5,282' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel I D 5 5 6,381' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 6 7,297' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 7 8,081' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 8 8,862' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 6 9 9,461' 1.901 4.25 GLM 8rd BK-2 Latch Mandrel 10 9,953' 1.901 3.75 GLM 8rd T-1 Latch Mandrel 11 10,384' 1.901 3.75 GLM 8rd T-1 Latch Mandrel,Orifice 12 10,435' 1.875 4.5 On/off tool w/X Profile DV @ 7,869' L , 13 10,437' 1.940 4.625 AS1-X Ret.Packer 7 14 10,450' 1.791 3 XN Landing Nipple I 15 10,455' 2 3 WLEG PERFORATION DATA I 68 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date Detail 10,564' 10,590' 10,354' 10,379' 26 6 3/28/01 2-1/2"PJ G I 09 10,610' 10,620' 10,397' 10,407' 10 6 3/28/01 2-1/2"PJ 10,627' 10,645' 10,413' 10,430' 18 6 7/11/97 2-1/8"Enerjet H-1 7.5/8" 10,629' 10,647' 10,415' 10,432' 18 6 2/4/13 3-3/8"HC Guns IEl 10 10,659' 10,685' 10,443' 10,468' 26 6 Future 3-3/8"HC Guns I I H-2 1 1b11 10,660' 10,687' 10,444' 10,470' 27 6 7/11/97 2-1/8"Enerjet 10,693' 10,724' 10,475' 10,504' 31 6 2/4/13 3-3/8"HC Guns D4 12 H-3 . 13 10,695' 10,737' 10,477' 10,517' 42 6 7/11/97 2-1/8"Enerjet 11 14 H-5 ±10,745' ±10,785' ±10,524' ±10,562' ±40 6 Proposed TBD H-8 10,819' 10,852' 10,594' 10,625' 33 6 2/3/13 3-3/8"HC Guns G = 15 Hemlock 10,822' 10,835' 10,596' 10,609' 13 4 9/13/1975 H1 = Hemlock 10,845' 10,884' 10,618' 10,655' 39 4 9/13/1975 H2 H3 Hemlock 10,894' 10,910' 10,664' 10,679' 16 4 9/13/1975 H5 H8 = Hemlock - Tag fill @ 10,860'on 2/3/2013 5-1/2" A.'. „ . -. \ TD=11,030'MD;10,790'ND/PBTD=11,010'MD;10,773'ND HoleAngle=25°/KOP=7,000' Updated by DMA 10-10-13 THE STATE 01 GOVERNOR SEAN PARD?ELL January 14, 2014 CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7009 2250 0004 3911 3545 Mr. Luke Saugier N. Kenai Asset Team Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Re: Defeated Safety Valve System Missing Annulus Valves Swanson River Field Dear Mr. Saugier: laska 0-m� and G, ae 1-1 y ter" �TTLfi7FQRhf.y, 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 On December 9, 2013 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector accompanied by Hilcorp Alaska LLC (Hilcorp) representatives performed safety valve system inspections at well sites within the Swanson River Field, Soldotna Creek Unit (SCU). Two wells equipped with rod pumps — namely SCU 12A-04 (PTD 1740210) and SCU 41A-08 (PTD 1940850) — were found to have the controller in bypass mode, preventing the pump from tripping (i.e., the low pressure actuating device was found defeated). Also during the AOGCC inspections, SCU 24A-09 (PTD 1750220) was observed to be without a pressure gauge to monitor the outer annulus. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system and failure to equip wells with the required pressure gauges. Each is a violation of State regulations. Please note that this is a second notice regarding SCU wells with defeated surface safety systems and a missing OA pressure gauge. The AOGCC Inspector's report indicates that the controllers were placed back in service for SCU 12A-04 and SCU 41A-08 and both subsequently passed the required tests (tripping the pump offline at a pressure in compliance with AOGCC regulation). Hilcorp is reminded that 20 AAC 25.265 requires a completed well to be equipped with a functional safety valve system. By letter dated September 24, 2013 AOGCC approved a variance for all Swanson River Unit wells that are equipped with rod pumps allowing them to operate with an alternate surface safety system; in lieu of a surface safety valve, approval was granted for the use of "functionally equivalent components that are common to rod pump wells that automatically terminate production from the well" as provided by 20 AAC 25.265(o)(1). Notice of Violation — Swanson River Field January 14, 2014 Page 2 of 3 AOGCC recognizes there may be legitimate operating reasons for defeating a well safety valve system. Paragraph (m) of 20 AAC 25.265 establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was no tag observed on either well that would indicate an inoperable safety system for the rod pump wells. Regulation 20 AAC 25.200(c) requires wellhead equipment to include appropriate gauges and valves installed in the tubing, casing -tubing (inner) annulus, and casing -casing (outer) annuli. AOGCC records indicate SCU 24A-09 was worked over to replace the tubing and perforate with work completed and production commencing in February 2013. The reason for delaying the installation of required pressure monitoring equipment is unclear. Hilcorp is directed to accomplish the following actions within 14 days of receipt of this letter: - install an appropriate outer annulus pressure gauge on SCU 24A-09; - provide AOGCC with an explanation of how these non -compliances happened and what has been or will be done in the future to prevent recurrence at Hilcorp-operated well sites in Alaska. The AOGCC reserves the right to pursue enforcement action in connection with the defeated surface safety systems on SCU 12A-04 and SCU 41A-08 and the missing outer annulus pressure gauge on SCU 41A-09 as provided by 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, CathyP. oerster Chair, C mmissioner Attachment cc: P. Brooks AOGCC Inspectors Notice of Violation — Swanson River Field January 14, 2014 Page 3 of 3 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the appljcation for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not i cluded in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period ruts until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. II • •oldotna Creek Unit Well: SCU 24A -09 SCHEMATIC Completion Date: 02/04/13 PTD: 175 -022 Hilcora Alaska. LLC API: 50- 133 - 20273 -00 RKB to TBG Hanger = 15.00' 7 S'G "/3 Cameron 3" Type "H" BPV CASING DETAIL Grad 1 Size Wt Conn Top e 18" L ... 18" 104 Surf 80' 10 -3/4" 40.5 K -55 Butt Surf 3,395' 33.7 P -110 Butt Surf 60' 26.4 N -80 Butt 60' 4,137' r"-.1 2 7 29.7 N -80 8rd LT &C 4,137' 6,061' 33.7 P -110 8rd LT &C 6,061' 9,712' 5 -1/2" 20 N -80 N -80 9,519' 11,028' 10 -3/4" L , TUBING DETAIL. 1 3 1 2 -3/8" I 4.6 L -80 1 EUE I Surf 1 10,455' 7 -5/8" Stage Collar @ 7,869' T JEWELRY DETAIL No. Depth OD Item 1 15' - - Tubing Hanger, Shaffer, 2 -3/8 CIW BPVP 2 2,291' 1.901 4.25 GLM 8rd, BK -2 Latch Mandrel I-1) 5 3 3,994' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 4 5,282' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 5 6,381' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 6 7,297' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel F-16 7 8,081' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 8 8,862' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 9 9,461' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 10 9,953' 1.901 3.75 GI Mandrel DV @ 7,869' L , 11 10,384' 1.901 3.75 GLiv� < ri Mandrel, Orifii. 12 10,435' 1.875 4.5 On /off tool w/ X Profile I 7 13 10,437' 1.940 4.625 AS1 -X Ret. Packer 14 10,450' 1.791 3 XN Landing Nipple 15 10,455' 2 3 WLEG r 8 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date Detail I 9 10,564' 10,590' 10,354' 10,379' 26 6 3/28/01 2 -1/2" P.I G 10,610' 10,620' 10,397' 10,407' 10 6 3/28/01 2-1/2"1 7 -5/8" 4 , 10,627' 10,645' 10,413' 10,430' 18 6 7/11/97 2 - 1/8" Enerjet i 10 H -1 10,629' 10,647' 10,415' 10,432' 18 6 2/4/13 3 -3/8" HC Guns H 11 10,659' 10,685' 10,443' 10,468' 26 6 Future 3 -3/8" HC Guns H -2 a _, kj ILL_ 10,660 10,687 10,444' 10,470' 27 6 7/11/97 2 -1/8" Enerjet . -. -13 10,693' 10,724' 10,475' 10,504' 31 6 2/4/13 3 -3/8" HC Guns xN I14 H-3 LJ 10,695' 10,737' 10,477' 10,517' 42 6 7/11/97 2 -1/8" Enerjet a H -8 10,819' 10,852' 10,594' 10,625' 33 6 2/3/13 3 -3/8" HC Guns G = 15 Hemlock 10,822' 10,835' 10,596' 10,609' 13 4 9/13/1975 H1 = H2 - Hemlock 10,845' 10,884' 10,618' 10,655' 39 4 9/13/1975 H3 = Hemlock 10,894' 10,910' 10,664' 10,679' 16 4 9/13/1975 H8 = Hemlock = Tag fill @ 10,860' on 2/3/2013 5 -1/2" / TD = 11,030' MD; 10,790' TVD / PBTD = 11,010'MD; 10,773' TVD Updated by DMA 04-08-13 Hole Angle = 25 ° / KOP= 7,000' SCANNED MAY 1 4 2013 STATE OF ALASKA t, 1) : 7 ; s, Z13 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon LJ Repair Well U Plug Perforations 11 Perforate L] Other L] Run Completion Performed: Alter Casing ❑ Pull Tubing el Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ — 175 -022 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 e" 50- 133 - 20273 -00 ^ CO 7. Property Designation (Lease Number): 8. Well Name and Number: I FEDA028997 ■ Soldotna Creek Unit (SCU) 24A -09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,030 feet Plugs measured N/A feet true vertical 10,790 feet Junk measured 10,860 (fill) feet Effective Depth measured 10,860 feet Packer measured 10,437 feet true vertical 10,632 feet true vertical 10,235 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 18' 80' 80' Surface 3,395' 10 -3/4" 3,395' 3,395' 3,310 psi 1,580 psi Intermediate 9,712' 7 -5/8" 9,712' 9,571' 6,020 psi 3,400 psi Production 1,509' 5 -1/2" 11,028' 10,790' 9,190 psi 8,830 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED APR 2013 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.6# / L -80 10,455' MD 10,252' TVD Packers and SSSV (type, measured and true vertical depth) AS1 -X Ret. Pkr 10,437' MD 10,235' TVD N /A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 230 200 Subsequent to operation: 7 90 336 1180 200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 12 . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil „ El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 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: 312 -368 Contact Chad Helgeson Email chelgeson a.hilcoro.com Printed Name Chad Helgeson Title Operations Manager / Signature ,�° ff� Phone 907-777-8405 Date / Z>�5�3 Lj.�r.1 � Form 10 -404 Revised 10 2+ * Ws APR 0 2 2013 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary OeatSu a p Y Well Name API Number Well Permit Number Start Date End Date SCU 24A -09 50- 133 - 20273 -00 175 -022 9/30/12 2/5/13 Daily Operations: 09/30/2012 - Sunday Laid containment for WOR and Equipment, MIRU Williams WOR 405. 10/01/2012 - Monday Finshed final RU. HU kill line to tbg wing and bullheaded 30 bbls down tbg. 10/02/2012 - Tuesday RD equipment, get ready for move to SRU 23B -22. 01/15/2013 - Tuesday ND Well head, NU 11" Bop stack, NU HCR Valves, Finished RU and winterization package. MIRU Pollard test unit, tested Bops and surface equipment, tested 250 low and 3000 high on bop's, test 250 low and 1500 high on annular preventer, test was waived by Jim Reg at 2 pm on the 15 th. 01/16/2013 - Wednesday Finished testing Bop's and surface equipment. Blew well down for 5 hrs while waiting on lubricator, finally bled all pressure off tubing thru 2 way check, Pulled 2 way check. Made up pup joints in top of 3- 1/2" 8 RD hanger, attempted to pull hanger. Picked up to 106K and hanger came out, continued picking up on tbg to try and release seal assembly. Worked tbg up and down from neutral weight of 94K to 130K. Worked for 1 hr and tried pulling up to 140K, locked break handle down and watched for 7 rains. Tbg hanger threads pulled out on bottom of hanger. This caused tbg to fall down hole. Picked up 2 jts of 2 -7/8" PH -6 WS, made up 5 -3/4" overshot loaded with 3 -7/8" grapple. TIH and tagged top of fish, made 1 round with tbg and engaged fish into grapple /overshot. PU and started POOH w/ 3 -1/2" IBT Tbg. TOH LD overshot and fish, LD 67 joints of 3 -1/2" Production Tbg. 01/17/2013 - Thursday Continued LD 3 -1/2" Production Tbg, LD total of 97 joints. Racked and tallied 100 jts of 2 -7/8" PH -6 WS, MU 6 -5/8" Pirahna mill, 2 -5' Boot baskets, 6 4 -1/2" drill collars and 87 jts of 2 -7/8" WS. TIH, tagged TOF @ 3,025'. Milled up 8' of fish until got steady torque. Pumped 890 Bbls of produced saltwater while milling, getting very little circulation back after 620 Bbls pumped. Started SOOH W/ 2 -7/8" PH -6 Tbg, SO W/ 28 stands. 01/18/2013 - Friday Finished SOH W/ 2 -7/8" WS, LD mill, mill showed good sign of wear of tbg. TIH W/ 5 -3/4" Overshot loaded with 3 -1/2" basket grapple. Engaged grapple on TOF @ 3,041'. Attempted to work seals loose with no sucess. MIRU Pollard E -Line. Tried to make a run with 2.24" GR, could not get past overshot. POOH, GR filled with metal shavings. RBIH W/ GR and kicked pump on, pumped plug down to 5,815'. Contined pumping up to 5 BBI /min rate, caught pressure and pressured up to 2,400 psi and broke back to zero. Weight indicator on rig lost tension we had pulled on tbg. RD E -Line unit and started SOH W/ 2 -7/8" WS. LD Overshot and fish. Started LD 3 -1/2" production string. LD total of 151 jts. 01/19/2013 - Saturday Continued LD 3 -1/2" production tbg. LD total of 302 jts and 5 subs. LD 34 jts of 2 -7/8" and 4 gas lift mandrels. Recovered 10 inches of seal assembly. MU 4 -5/8" Burn Shoe Assembly. TIH with 331 joints of 2 -7/8" PH -6 WS. Tagged packer and started burning over slips. 01/20/2013 - Sunday • • Continued Burning over packer. Burned over packer from 10,484' to 10,487', packer started to move down hole, chased packer down to 10,641'. Attempted to make hole with no success. POOH W/ Burn shoe. Burn shoe was worn 90 %. MU 2.43" Spear Assembly. TIH down to 10,641' and attempted to engage spear in top of packer. PU and had a 15,000 pd over pull. Continued SOOH. LD packer. 01/21/2013 - Monday MIRU Pollard Slickline Unit. MU 2.0 Pump bailer. RIH and tagged obstruction @ 10,614' wim, stroked several times, fill very hard and sticky. POOH. Recovered 3 cups of sand. Made another run wih 2.0 DD Bailer, tagged same and tried to work down, recovered 1/2 cup of sand. RDMO. MU 2 -7/8" Mule shoe on 2 -7/8" PH -6 WS. TIH, tagged sand @ 10,634' and began washing down hole, washed down to 10,746', recovered sand and metal debris. Had to beat thru hard spot @ 10,715'. Circulated well clean. SOH W/ 2 -7/8" PH -6 WS. SO total of 72. 01/22/2013 - Tuesday Continued SOOH W/ 2 -7/8" PH -6 WS and Mule shoe. SO total of 169 stands and LD 3 single and mule shoe. Mule showed signs of metal. MIRU Pollard siicklie unit, MU 3 -1/2" magnet. RIH, tagged top of re -entry guide at 10,614' wim. POOH and recovered a few large pieces of metal and a cup full of shavings. RBIH W/ same magnet and magnet backed off down hole. POOH, RDMO Slickline Unit. Made ready to test Bop's, Jeff Jones with AOGCC out to witness test. Jeff Jones shut operations down due to not being able to prove nitrogen bottles had been tested, we wil be shut down until bottles can be tested and recorded. 01/23/2013 - Wednesday Received tools to test and record pre - pressures on nitrogen bottles on accumulator. Tested accumulator bottles, each bottle test with 0 psi on system. The following bottles tested @: Bottle 1- 1,050 psi; Bottle 2 - 1,000 psi; Bottle 3 -1,050 psi; Bottle 4 - 1,050 psi; Bottle 5 - 1,000 psi; Bottle 6 -1,075 psi; Bottle 7 -1,000 psi; Bottle 8 - 1,000 psi; and Bottle 9 - 1,000 psi. RU Pollard Slickline Unit. RIH W/ 2.5" JDS in 4.5" bail guide, tagged @ 10,680'. POOH, metal marks on inside lip of guide. RIH W/ 2.5" JDS in 3.75" bail guide, tagged @ 10,717'. POOH, had to spang up to get out, metal marks on inside lip of guide, pins not sheared on tool. RBIH W/ same to 10,719'. POOH, still no recovery. RIH W/ 2.5" RS in 4.5" bail guide, tagged @ 10,705'. POOH, very sticky. RIH W/ 3.5" LIB, tagged @ 10,720'. POOH, no marks on LIB. RIH W/ 3.75" LIB, tagged @ 10,720'. POOH, no marks on LIB. RIH W/ 2" Pump Bailer with flapper bottom, tagged @ 10,720'. POOH, no recovery, very sticky. RIH W/ 2.5" LIB, tagged @ 10,720'. POOH, no marks on LIB. RIH W/ 2.25' drive down bailer, tagged @ 10,720'. POOH, recovered 1/2 cup of sticky sand. RDMO Pollard Slickline Unit. MU 4 -1/2" pinged shoe assembly on 2 -7/8" PH -6 WS. TIH, Tagged top of fish (magnet) at 10,739'. Circulated and washed down to 10,743' and attempted to get to 3 -1/2" OD Magnet into pinged shoe. Circulated welbore clean and POOH. SOOH W/ 76 stands of WS. 01/24/2013 - Thursday Continued SOOH W/ pinged, cut lip shoe on 2 -7/8" WS,. LD shoe with magnet and perf gun debris. MIRU Pollard Slickline Unit. RIH W/ 3 -1/2" magnet, tagged @ 10,720'. POOH, no recovery. RIH W/ 2" Drive down bailer, tagged @ 10,720'. Worked bailer several times, very sticky. POOH, no recovery. RBIH W/ 3" LIB, tagged same. POOH, No marks on LIB. RDMO Pollard Unit. MU 3.75" Bulldog bailer with mule shoe, PU 16 joints of 2 -7/8" 8 RD between pump and flapper. TIH on 2 -7/8" PH -6 WS. Tagged. Started SOOH W/ 2 -7/8" WS and Bulldog Bailer. SOOH W/ 168 stands of PH -6 and LD 2 joints of 2 -7/8" 8 RD. 01/25/2013 - Friday Continued LD 2 -7/8" 8RD and bulldog bailer, recovered 3 gallons of sand and metal debris. MIRU Pollard slickline Unit, RIH W/ 4.5" magnet on bowspring centralizer, down to 9,455 'wlm. POOH, recovered metal shavings. RIH W/ 3.5" magnet on bowspring centralizer, down to 10,721' wlm. POOH, recovered metal shavings. RBIH W/ 3.5" LIB on bowspring centralizer, s • tagged @ 10,721' wlm. POOH, LIB had no markings on face. RIH W/ 1 -3/4" Drive Down Bailer to 10,721', worked tools, very sticky. POOH, recovered full bailer of sand. RBIH W/ 1 -3/4" Drive Down Bailer to 10,726', worked tools. POOH, recovered 1/2 full bailer of sand. Bailer had metal marks on bottom. RBIH W/ 1 -3/4" Drive Down Bailer to 10,724', lost 2 ft, worked tools. POOH, broken flapper, recovered very little sand. RBIH W/ 2 -1/4" Drive Down Bailer to 10,720', worked tools. POOH, no recovery. RBIH W/ 1 -3/4" Drive Down Bailer to 10,724', worked tools. POOH, recovered 1/2 full bailer of sand. RBIH W/ 2.65" LIB on bowspring centralizer, tagged @ 10,721' wlm. POOH, LIB had no markings on face. RBIH W/ 1 -3/4" Drive Down Bailer to 10,724', worked tools. POOH, recovered 1/2 full bailer of sand. RIH W/ 4.25" GR, tagged bottom @ 10,725'. Beat down with GR, made no hole. POOH. RBIH W/ 1 -3/4" Drive Down Bailer to 10,727', worked tools. POOH, recovered 1/2 full bailer of sand. RBIH W/ 3.65" LIB on bowspring centralizer, tagged @ 10,727' wlm. POOH, LIB had no markings on face. RBIH W/ 4" Drive Down Bailer to 10,727', worked tools. POOH, no recovery, metal marks on new bottom. RIH W/ 3.5" magnet on bowspring centralizer, down to 10,727' wlm. POOH, magnet empty. RIH W/ .75" prong, tagged bottom @ 10,727'. Beat on debris. 01/26/2013 - Saturday RBIH W/ 1 -3/4" Drive Down Bailer to 10,727', worked tools. POOH, recovered 6" of sand. RIH W/ 3.5" magnet on bowspring centralizer, down to 10,727' wlm. POOH, recovered metal shavings. RBIH W/ 2.70" LIB on bowspring centralizer, tagged @ 10,727' wlm. POOH, LIB had no markings on face. RDMO Pollard Slickline Unit. MU 4 -5/8" OD Bladed Junk mill Assembly. TIH on 2 -7/8" PH -6 WS. Tagged top of obstruction @ 10,743'. Milled down to 10,751'. Circulated hole clean with a 15 Bbl gel sweep and 267 Bbls of produced saltwater. Hung back power swivel and started SOOH W/ 2 -7/8" WS. 01/27/2013 - Sunday Continued SOOH W/ 2 -7/8" PH -6 WS. SO with 166 stands, LD 2 boot baskets and 4 -5/8" bladed junk mill, boot baskets completely full of metal, washers and gun debris. MIRU Pollard Slickline Unit, RIH W/ 3.5" magnet to 10,731'. POOH, recovered 1/2 cup of metal chunks. RIH W/ 3.5" LIB on bowspring centralizer, down to 10,729' wlm. Tagged, POOH, LIB had no marks on face. RBIH W/ 1.75" Drive down Bailer on bowspring centralizer, tagged @ 10,733' wlm. Worked tools several times. POOH, recovered very little metal. RBIH W/ 1 -3/4" Drive Down Bailer to 10,734', worked tools. POOH, no recovery. RBIH W/ 2" Pump Bailer to 10,734', worked tools. POOH, recovered very little sand. RIH W/ 1 -3/4" magnet on bowspring centralizer, down to 10,734' wlm. POOH, recovered metal shavings. RBIH W/ 1 -3/4" magnet on bowspring centralizer, down to 10,736' wlm. POOH, recovered chunks of metal. RBIH W/ 3" pump bailer to 10,735', worked tools. POOH, recovered metal. RIH W/ wiregrab down to 10,736', worked tool to break up fill. POOH, RBIH W/ 3" pump bailer to 10,735', worked tools. Started out of hole and lost bottom of bailer, rod pulled out. RIH W/ 2.5" JDC, tagged bailer bottom @ 10,735', worked tools, tool would not latch. POOH, waited for bell guide from shop. RBIH W/ 1 -3/4" magnet on bowspring centralizer, down to 10,734' wlm. POOH, recovered metal shavings. RIH W/ 3.65" Bell Guide and 2.5" JDC to 10,735', worked tool, tool would not latch. POOH, RIH W/ 4.25" Bell Guide and 2.5" JDC to 10,735', worked tool, latched fish and POOH. Cut line and re -tied rope socket, checked tool string. RBIH W/ 2.75" Drive down bailer to 10,738', worked tools. POOH, recovered 1 cup of metal. 01/28/2013 - Monday • RIH W/ 2.75" Drive Down Bailer, tagged 10,738' wlm. POOH, recovered 1 cup of metal. RIH W/ 1.75" Earth Magnet to 10,738'. POOH, recovered 1/4 cup of metal. RIH W/ 1.75" Drive Down Bailer, tagged 10,737' wim. POOH, recovered 1 cup of metal. RIH W/ 3.75" LIB to 10,734', stroked top of obstruction. POOH, LIB had no markings on face. POOH. RIH W/ 1.75" Bailer, tagged 10,733' wlm, worked tools. POOH, come out empty. RIH W/ 4.29" Gauge Ring, tagged @ 10,733' wlm. Beat down multiple times, POOH. RBIH W/ 3.7" LIB down to 10,733', tagged obstruction and POOH. Still no marks on LIB. RIH W/ 1.75" Drive Down Bailer, tagged 10,737' wlm. POOH, recovered 1/2 cup of metal. RDMO Pollard Slickline Unit. MU 4 -5/8" bladed mill with 4 boot baskets. TIH on 2 -7/8" PH -6 WS. TIH W/ 168 stands of WS, tagged obstruction @ 10,743', washed and worked down to 10,752'. Well continually drinking fluids while triing to circulate clean. Pumped 2 gel sweeps and total of 1,260 Bbls of produced SW down hole. 01/29/2013 - Tuesday Continued circulating gel sweeps, lost circulation, swivel and pumped 5 joints up hole off bottom, shut down operation. Mixed and pumped 10 Bbl salt pill to stop up perforations, let sit for 30 rains, started pumping produced water again, got 75 percent circulation back, Had to wash and drill last 5 joints of 2 -7/8" WS. Tagged top of Re -entry guide @ 10,752'. Circulated 3 -15 Bbl gel sweeps, recovering sand and metal debris. Hung swivel back in the derrick, started SB 2 -7/8" WS, stood back 163 stands, LD 4 -5/8" bladed junk mill and 4 boot baskets. All 4 boot baskets full of metal and sand. 01/30/2013 - Wednesday MIRU E -Line Unit. Run Neutron Gamma Ray Log from 10,750'- 3,700'. POOH, RDMO. Tested Bop's, tested manifold to 250 on low and 3000 on high. Bop's tested same, tested annular preventer to 250 low and 1500 high. Witness waived by Jim Regg, AOGCC 1/28/13. All tested good. MU 3 -1/8" X 1 -1/2" tappered tap on 2 -7/8" PH -6 WS. TIH to top of re -entry guide @ 10,752'. Engaged tap with power swivel, shut down swivel and PU on WS. Pulled 18K over string weight and pulled free, sat back down on re -entry guide and engaged tap again, left swivel turning to right and backed overshot below tap off. PU and had small amount of drag. Jarred down on tbg looking up to ensure tap was buried inside re -entry guide, again leaving swivel turning to right backed off overshot. POOH w/ re -entry guide and WS. SOOH w/ 100 stands of 2 -7/8" PH -6 WS. 01/31/2013 - Thursday Continue SOOH w/ 2 -7/8" WS, total of 167 stands, LD tapered tap with fish (overshot /grapple). MU 4' burn shoe on 1 jt of wash pipe. TBIH on 2 -7/8" WS, went over top of fish @ 10,753' and wash down to 10,785', circulated well clean. SOOH w/ 2- 7/8" WS, LD wash pipe and burn shoe. MU overshot loaded with 2 -3/8" grapple. TBIH, tagged top of fish @ 10,753'. Engaged grapple and attempted to POOH, straight pulled 15K over string weight and something broke free. Started SOOH w/ WS and overshot with fish. 02/01/2013 - Friday Continued SOOH w/ WS and fish, LD 28' long cut joint and 4' of a parted perforated joint. MU new overshot loaded with 2- 3/8" grapple. TBIH, engaged top of fish @ 10,783'. Jarred on fish for 10 mins, something broke free. SOOH, LD overshot /grapple, recovered 3.75' of perforated joint. MU new overshot loaded with 2 -3/8" grapple. TBIH, engaged top of Y fish @ 10,787'. Jarred on fish for 20mins, something broke free. Weight indicator shows to be dragging around 40K over string weight. SOOH, stood out with 56 stands, when ulling fish throu h liner top, saw each packer pull thru, on last packer had to jar several times to get free. " to c- 02/02/2013 - Saturday Continued SOOH w/ 2 -7/8" WS, LD first 2 packers and blast joints between 2nd and 3rd packer. Packer came apart in top of packer. MIRU sLick -line unit. RIH w/ 2 -1/2" drive down bailer, tagged bottom @ 10,878' wim. POOH, RBIH w/ 3.5" LIB, tagged bottom @ 10,878' again. POOH. RDMO. MU Spear with 2 -3/8" grapple. TIH on 2 -7/8" WS. Tagged top of packer @ 10,860', engaged grapple and started TOH, LD 2 -7/8" WS. LD total of 310 jts of WS. 02/03/2013 - Sunday Continue TOH LD 2 -7/8" PH -6 WS, LD spear, no fish recovered. MIRU slickline. RIH w/2.5" drive down bailer, tagged bottom @ 10,868' wlm, worked tools a few times and POOH. Recovered no sample and bailer bottom had metal marks on it. RBIH w/ 3.25" LIB, tagged @ 10,869' wlm. POOH, no marks on LIB. RDMO slickline. MIRU E -Line unit. MU 33' perf gun on Gamma • • Ray /CCL. RIH, tagged bottom @ 10,860' elm. Logged up to 7,000'. Dropped back down to desired depth and fired first gun. Perforated H8 from 10,819'- 10,852'. POOH, MU 2nd gun, 31' gun. RIH and correlated depths, attempted to fire 2nd gun, could not get to fire, started out of hole with gun and found E -Line was frayed. POOH, RD E -line unit. MIRU new E -Line Unit. MU number 2 gun, 31' gun on Gamma Ray /CCL. RIH to bottom, re- logged up to 7,000'. Dropped down to desired depth and fired 2nd gun, perforated H3 from 10,693'- 10,724'. POOH, verified all guns fired. MU 3rd gun, RIH w/ 26' gun on CCL. Made 1 pass with CCL, correlated depth, fired gun #3, perforated H2 from 10,659'- 10,685'. POOH, verified all guns fired. MU Gun #4. RIH w/ 18' gun and CCL, made 1 pass with CCL, correlated depths and fired gun #4. Perforated H1 from 10,629'- 10,647'. POOH, all guns fired. RDMO E -Line unit. All guns used where 3 -3/8" HC 6 SPF Perf guns. 108' of perfs. ✓ 02/04/2013 - Monday Finished rigging down E -Line unit and equipment. ND shooting flange, made ready to run 2 -3/8" production. Unloaded and talleyed 330 Jts of 2 -3/8" 8 Rd tbg, MU WLREG, XN nipple on AS1X 5 -1/2" Tri -point packer, on /off tool, 1 jt of 2 -3/8" tbg and 1st gas lift mandrel. Continued TIH w/ 2 -3/8" 4.7# L -80 EUE 8 RD and remaining gas lift mandrels. Set packer @ 10,443'. Landed hanger w/ 4,000 psi down on it. Tested casin &to 2,000 psi and tubing to 3 000 psi, charted both for 30 mins. Installed BPV in hanger, ND Bop's and NU well -head, tested void good. Tested tree to 5,000 psi, tested good. 02/05/2013 - Tuesday Cameron well head rep pulled BPV. Continued RD WOR and equipment. Rigged down winterization kit and all equipment. Set up ground thaw unit for flow lines and turned over to production. Swanson River Unit P Well: SRU 24A -09 SCHEMATIC Completion 175 Date: 02/04/13 PTD Hilcorp Alaska, LLC API: 50- 133 - 20273 -00 RKB to TBG Hanger = 15.00' Cameron 3" Type "H" BPV CASI DETAIL 1 Size Wt Grade Conn Top Bottom 18" 104 Surf 80' 18" 1 0 3/4" 40.5 K - Butt Surf 3,395' 33.7 P -110 Butt Surf 60' 7-5/8" 26.4 N -80 Butt 60' 4,137' 2 29.7 N -80 8rd LT &C 4,137' 6,061' 33.7 P -110 8rd LT &C 6,061' 9,712' 5 -1/2" 20 N -80 N -80 9,519' 11,028' 10 -3/4" Z , TUBING DETAIL 2 -3/8" 4.6 L -80 EUE Surf 10,455' »i i3 7 -5/8" Stage Collar @ 7,869' ID 4 JEWELRY DETAIL No. Depth ID OD Item 1 15' - Tubing Hanger, Shaffer, 2 -3/8 CIW BPVP 5 2 2,291' 1.901 4.25 GLM 8rd, BK -2 Latch Mandrel I 3 3,994' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 4 5,282' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 5 6,381' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 6 7,297' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel IS i 6 7 8,081' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel I 8 8,862' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 9 9,461' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 10 9,953' 1.901 3.75 GLM 8rd T -1 Latch Mandrel DV @ 7,869' L 11 10,384' 1.901 3.75 GLM 8rd T -1 Latch Mandrel, Orifice 17 12 10,435' 1.875 4.5 On /off tool w/ X Profile I 13 10,437' 1.940 4.625 AS1 -X Ret. Packer 14 10,450' 1.791 3 XN Landing Nipple 15 10,455' 2 3 WLEG i - 8 PERFORATION DATA IN 1 9 III Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date H -1 Detail MN 10,627' 10,645' 10,413' 10,430' 18 6 7/11/97 2 -1/8" Enerjet 7 -5/8" , 10,629' 10,647' 10,415' 10,432' 18 6 2/4/13 3 -3/8" HC Guns R 10 10,659' 10,685' 10,443' 10,468' 26 6 Future 3 -3/8" HC Guns II 11 H-2 10,660' 10,687' 10,444' 10,470' 27 6 7/11/97 2 -1/8" Enerjet 10 12 10,693' 10,724' 10,475' 10,504' 31 6 2/4/13 3 -3/8" HC Guns . A. • «.s I 13 H -3 isa Y4 14 10,695' 10,737' 10,477' 10,517' 42 6 7/11/97 2 - /8" Enerjet H -8 10,819' 10,852' 10,594' 10,625' 33 6 2/3/13 3 -3/8" HC Guns 15 Hemlock 10,822' 10,835' 10,596' 10,609' 13 4 9/13/1975 H1 = Hemlock 10,845' 10,884' 10,618' 10,655' 39 4 9/13/1975 H2 H3 = Hemlock 10,894' 10,910' 10,664' 10,679' 16 4 9/13/1975 H8 Hemlock - x ry 4 + i 4 : Tag fill @ 10,860' on 2/3/2013 5 -1/2" ilEdr isi #k KUL TD = 11,030' MD; 10,790' TVD / PBTD = 11,010'MD; 10,773' TVD Hole Angle = 25 °/ KOP= 7,000' Updated by DMA 03 -28 -13 Ferguson, Victoria L (DOA) :� 3 i From: Ferguson, Victoria L (DOA) Sent: Tuesday, January 08, 2013 2:01 PM To: Chad Helgeson Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Subject: RE: SCU 24A -09 BOP stack change (Sundry 312 -368) (PTD 175 -022) Chad, You have approval to use the Weatherford 5000 psi Shaffer BOP stack on the subject workover. Thanx, Victoria SCANNED APR 1 1 aoi3 From: Regg, James B (DOA) Sent: Monday, January 07, 2013 5:36 PM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Subject: FW: SCU 24A -09 BOP stack change (Sundry 312 -368) Disregard the performance info I sent you earlier. T g p yo e e That would have been relevant to the BOP stack in the approved Sundry, not what Hilcorp is now proposing. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Chad Helgeson f mailto:chelgeson@ hilcorp.com] Sent: Monday, January 07, 2013 5 :29 PM To: Regg, James B (DOA) Cc: donnierhuffmarayahoo.com; Wade Hudgens - (C) Subject: RE: SCU 24A -09 BOP stack change (Sundry 312 -368) Jim, We are wanting to use the Weatherford owned 11" Shaffer stack. My plan was to change out the stacks from what was approved in the Sundry. I am requesting the change from the AWS stack (approved in Sundry) to the Weatherford owned stack 5000 psi Shaffer stack. We will have variable rams to cover 2 -7/8" to 3 -1/2" pipe. When we go to run the completion we will change out the rams to 2 -3/8" and test them before we run the 2 -3/8" completion. Let me know if you need anything else. Chad From: Regg, James B (DOA) [mailto:jim.regg(aalaska.gov] Sent: Monday, January 07, 2013 1:41 PM To: Chad Helgeson Subject: RE: SCU 24A -09 BOP stack change (Sundry 312 -368) 1 • • Please clarify. Which 11" stack are you planning to use? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Chad Helgeson (mailto:chelciesonOhilcorp.com] Sent: Monday, January 07, 2013 11:55 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA); Regg, James B (DOA) Cc: Donna Ambruz; Wade Hudgens - (C); donnierhuffmanyahoo.com Subject: SCU 24A -09 BOP stack change (Sundry 312 -368) Hilcorp proposed to use the AWS#1 BOP stack for work approved on Sundry # 312 -368 for Swanson well SCU 24A -09. Another 11" stack is now available for rent and we would like to use the attached 11" 5M stack from Weatherford on this workover with the Williams Rig #405 in Swanson River, as opposed to the approved stack in the Sundry. Can you approve this stack for this workover, which we plan to start later this week? Please let me know if you have any questions or need additional information. Chad Helgeson Operations Manager North Kenai Asset Team Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907 - 229 -4824 2 • • II Swanson River SCU 24A -09 hko.t, '.Ia.1 a,1.11 ri. 01/07/2013 I Swanson River SCU 24A -09 Williams BOP 2013 v V 1 1 fri? r 1 ri ill III r 1 3.46' Shaffer 11" 5M 1%I ill iii (IL • Shaffer LWS y .....„1=-....-_---4 2.75' i _ p 11" 5M 0.- I - 2 _a 2 1/16 10M Choke and Kill __ ____ Valves TFT7-_l ■ . -. '� � ■ � . r � . ■ 2.00' I r . } a 11 5M I 8 i ) a .: : 7 + 1 I•I.Isidai.i�l t i ! 1 1.1 Fierier' 11" 5M X 2.00 9 "5M 1 - \ ali7l II 31r III i!i .. i i !. � 1 , i1 ' C �� ®l1 Nu ® ' 009 o ill o . ,is_ ...,,, ® e III i iil .11 ®(oJo 1i�1 �� C O • w \� THE STATE Alaska Oil and Gas '"' °fALAS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue �` Anchorage, Alaska 99501 -3572 ALAS �� OPL i]`- ` �i— Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson Operations Engineer 1'1 5 _ Q 9 . Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 24A -09 Sundry Number: 312 -368 Dear Mr. Helgeson: 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, t Cathy Py. Foerster Chair DATED this day of October, 2012. Encl. • Ac RECEIVED a ti • STATE OF ALASKA , S r,,- 8 ZO Z ALASKA OIL AND GAS CONSERVATION COMMISSION / O / l Z APPLICATION FOR SUNDRY APPROVALS .BOG C 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate In • Pull Tubing 0 • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Run Completion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Development El Exploratory ❑ 175-022 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. cv 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50- 133 - 20273-0 A,.. i.(-_ 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 cianges: Soldotna Creek Unit (SCU) 24A-09 Spacing Exception Required? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field / Pool(s): FEDA028997 • Swanson River Field / Hemlock Oil • 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): 11,030 , 10,790. 10,734 10,508 10,892 10,734 (Sand) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 18" 80' 80' Surface 3,395' 10 -3/4" 3,395' 3,395' 3,310 psi 1,580 psi Intermediate 9,712' 7 -5/8" 9,712' 9,569' 6,020 psi 3,400 psi Production 1,511' 5 -1/2" 11,028 10,791' 9,190 psi 8,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2"; 2-7/8"; 2 -3/8" 9.2#/N -80; 6.4 # /N -80; 4.6#/DK 9,440'; 10,517'; 10,911' Packers and SSSV Type: Baker F -1; (3) Baker FH Packers and SSSV MD (ft) and TVD (ft): 10,484' MD 10,279' TVD; 10,804' MD N/A 10,580' TVD; 10,837' MD 10,611' TVD; 10,886' 10,657' TVD; N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Ell Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/2/2012 Oil 0 • Gas ❑ ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson 777 -8300 Printed Name Chad Helgeson Title Operations Engineer Signature el � �� Phone 777 -8405 Date 9/28/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l 2.3( g Plug Integrity ❑ BOP Test 'Er Mechanical Integrity Test ❑ Location Clearance ❑ n r1 ¢ �� `` ?7 Other: k/ oP l r5 t 7 v 3-Pv Ps' Subsequent Form Required: /a ` 409- 3e:4,046/..._ APPROVED BY /9 Approved by: ( / r%` COMMISSIONER THE COMMISSION Date: 2 `/ Form 10 -403 Revised 1/2010 D �v ��� O 4 �� ` %� v Submit in Duplicate i✓ • Well Prognosis Well: SCU 24A -09 Hilcorp Alaska, LLC Date: 9/27/2012 Well Name: SRU 24A -09 API Number: 50- 133 - 20273 -01 Current Status: Shut in Oil Producer Leg: N/A Estimated Start Date: October 4 2012 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 175 -022 • First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1222987 Current Bottom Hole Pressure: — 2,000 psi @ 10,500' TVD (Static survey on nearby well conditions) Maximum Expected BHP: — 2,000 psi @ 10,500' TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Brief Well Summary Soldotna Creek Unit 24A -9 was drilled in 1977 to develop oil reserves in the H -8 sand lobe. The original hole was -- junked with a drill pipe fish and the well was sidetracked (24A -09). The original completion was in the lower H -8. A plug was set in the nipple above the lowest set of perfs and opened the sliding sleeves to produce the upper intervals. The well flowed until 1990. Unocal worked over the tubing in 1993, leaving the original completion in the well and recompleted shallower until 1997. • The well was worked over again in 1997 and added perforations in the upper hemlock. Well was shut -in in 2001. . Notes Regarding Wellbore Condition • Well current well status is shut in oil well. • Brief Procedure: 1. MIRU Williams pulling unit. Check fluid level (echometer), fill well with fluid volume, check fluid level again (determine static fluid level). If well will not hold fluid column, monitor fluid level in the morning to know where it is before starting work after shutdown. 2. Set BPV, ND tree, NU BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high. a. Notify AOGCC 24hrs in advance to witness 3. Pull tubing hanger 4. Work GBH -22 locator and seal assembly free from Baker F -1 Packer a logigi Mb 5. POOH with tubing and seal assembly 6. PU 4 -5/8" Packer milling assembly (mill, bumper sub, jars, drill collars) and 2 -7/8" PH -6 work string. 7. TIH and mill on packer until comes free and push down. 8. POOH and lay down milling assembly 9. TIH with spear BHA and retrieve packer mandrel and tubing tail. ✓ 10. POH, LD Spear BHA II • • H Well Prognosis Well: SCU 24A -09 Hilcorp Alaska, LLC Date: 9/27/2012 11. Depending on fluid level and circulation ,TIH with mule shoe assembly (60ft of 1.5" tubing w/ mule shoe, on bottom of 2 -7/8" PH -6 tubing) to clean out inside of lower tubing assembly 12. RU E -line, TIH with radial torch cutter and cut at 10,790' `�- 13. POOH with e-line RD e-line. 14. MU Spear for 2 -3/8" 4.6# tubing and fish with braided line. 15. POOH and lay down 16. RIH with overshot for 2 -3/8" tubing with bumper sub /jars and drill collars. 17. Latch tubing stub and jar packer free. a. Do not exceed the tensile strength of the of the 2 -3/8" 4.6# N -80 tubing (104,340 ft lbs) 18. If all the packers do not come free, but there was a little movement, rotate off CC safety joint. (12 turns to the right) 19. POOH with fish, LD fish and determine any tools left in the hole. a. If only 1 packer comes with the CC safety joint, RIH with overshot for CC safety joint and pull Baker FH packers, jarring free. b. If necessary rotate 12 turns to the right to release 2 ' CC safety joint. — c. Repeat as necessary until all the fish come out of the hole. 20. PU mill /bit and run to bottom to clean out bottom to +/- 10,920'. 21. POOH and LD 2 -7/8" work string. n, pt,.k 22. RIH and E -Line perforate H -1, 2, 3, 8 as shown on the proposed schematic with 3 -3/8" HC guns. • 23. RIH with packer and GLVs per design on 2 -3/8" tubing. Set packer at +/- 10,440'. Land tubing hanger with 8 -10K of compression on tubing. 24. Drop RHCP plug in well and test casing to 2,000psi and tubing to 3,000Qpsi, chart for 30 min ea. 25. Set BPV, ND BOPs, NU Tree, test tree to 5,000 psi. 26. RDMO workover rig and equipment. 27. Turn well over to production. 28. NU piping and flowlines. 29. Gas lift well, unloading fluid from well, SI well leaving gas lift pressure on well. 30. RU slickline, PT lubricator to 2000 psi Hi 250 low. 31. RIH and pull RHCP prong and plug 32. Start production 33. Notify AOGCC of SSV testing within 5 days of brining well online. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics (AWS 11" BOP to be used on Williams Rig) • • . Swanson River Field SCHEMATIC Well # SCU 24A -9 HilcorpAla'in.l,l.0 Completed 4/5/1997 RKB to TBG Hgr = 17.00' CASING DETAIL S ize Wt Grad Conn Top Bottom Cameron 3" Type "H" BPV e 18" 104 Surf 80' /I n 1 10 -3/4" 40.5 K -55 Butt Surf 3,395' 33.7 P -110 Butt Surf 60' la 7-5/8" 26.4 N -80 Butt 60' 4,137' 29.7 N -80 8rd LT &C 4,137' 6,061' I 33.7 P -110 8rd LT &C 6,061' 9,712' 1b 5 -1/2" 20 N -80 N -80 9,519' 11,028' I TUBING DETAIL 3 - 1/2" 9.2 N - Butt Surf 9,440' L ' 1C .. 2 - 7/8" 6.4 N -80 Butt 9,440' 10,517' 2 -3/8" 4.6 10,771' 10,911' 7 -5/8" Stage Collar @ 7,869' DV @ 7,869' Z 1d \ JEWELRY DETAIL NO. Depth Item 2 1 17' 3 -1/2" 8rd tbg hgr, 8rd x butt xover )))) lad Macco 3 -1/2" x 1" SMO -1 GLM @ >< __ 4800', 7000', 8400' and 9400' ei'''' v 4'� 2 9,440' 3 -1/2" x 2 -7/8" butt xover /] Mt'•• 4 1 0,484' Baker F -1 packer, 2 -7/8" x 5 -1/2" w/ a 11' seal assembly 1 d 5 10,506' Otis "X" nipple, 2.313" ID 4 O g � 6 10,517' 2 -7/8" Tbg tail (mule shoe re- entry) 5 7 10,771' 2 -3/8" re -entry guide j' 8 10,801' 2 -3/8" Otis "XA" sleeve _ 6 ( 9 10,804' 2 -3/8' x 5 -1/2" Baker FH packer Sand Tagged = 10 i 10,811' Otis "5" nipple position #3 @ 10,734' on 7 11 10,812' One 2 -3/8" blast joint h , Y� ✓� / 10,832' Brown "CC" safety joint 8-23-12 J G v� l / 12 10,834' Otis "XA" sleeve XA 8 1.1) O 13 10,837' 2 -3/8' x 5 -1/2" Baker FH packer 1 E. 9 kvo 1\ 14 10,843' Otis "5" nipple position #2 15 10,844' Two 2-3/8" blast joints S 10 / ( - V 10,882' Brown "CC" safety joint 11 16 10,883' Otis "XA" sleeve 17 10,886' 2 -3/8'x 5 -1 /2" Baker FH packer XA 12 Camco 2 -3/8" "D" nipple w /plug set in 13 18 10,892' 9/77 (Unable to pull plug with several 4 ,,,, S 14 attempts) 19 10,893' One 2 -3/8" blast joint 15 20 10,911' Baker 2 -3/8" shear out sub PERFORATION DATA XA 16 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Date 17 H - 1 10,627' 10,645' 10,413' 10,430' 6 7/11/97 18 H - 2 10,660' 10,687' 10,444' 10,470' 6 7/11/97 19 H -3 10,695' 10,737' 10,477' 10,517' 6 7/11/97 Hemlock 10,822' 10,835' 10,596' 10,609' 4 9/13/1975 20 Hemlock 10,845' 10,884' 10,618' 10,655' 4 9/13/1975 Hemlock 10,894' 10,910' 10,664' 10,679' 4 9/13/1975 PBTD = 11,030' TD = 11,010' Revised By TDF 9/21/2012 Hole Angle = 25 ° , KOP= 7,000' 0 • , a n Swanson River Field PROPOSED Well # SCU 24A -9 flacon) .alaska.L1.0 Future Completion RKB to TBG Hanger = 17.00' CASING DETAIL Cameron 3" Type "H" BPV Size wt Grad Conn Top Bottom e 18" 104 Surf 80' 1 10 -3/4" 40.5 K -55 Butt Surf 3,395' 33.7 P -110 Butt Surf 60' 26.4 N -80 Butt 60' 4,137' 7-5/8" 29.7 N -80 8rd LT &C 4,137' 6,061' 33.7 P -110 8rd LT &C 6,061' 9,712' 5 -1/2" 20 N -80 N -80 9,519' 11,028' 1 y 2 TUBING DETAIL 2 -3/8" 1 4.6 1 1 1 Surf ( 10,455' L , 7 -5/8" Stage Collar @ 7,869' 1 O3 JEWELRY DETAIL NO. Depth ID OD Item 1 § 4 1 15' - - Tubing Hanger, Shaffer, 2 -3/8 CIW BPVP • 2 ±2,400' 1.901 4.25 GLM 8rd, BK -2 Latch Mandrel N 3 ±4,200' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel .,l') 4 ±5,400' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 1 5 ±6,350' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 1 115 6 ±7,100' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 7 ±7,800' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 8 ±8,400' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 9 ±9,250' 1.901 4.25 GLM 8rd BK -2 Latch Mandrel 10 ±9,750' 1.901 3.75 GLM 8rd T -1 Latch Mandrel 1 116 11 ±10,400' 1.901 3.75 GLM 8rd, orifice T -1 Latch Mandrel 12 ±10,430' 1.87 3 On /off tool w/ x- nipple 13 ±10,440' 1.978 4.14 Arrowset mechanical packer . 14 ±10,450' 1.791 3 XN- Nipple 15 ±10,455' 2 3 WLREG 1 117 DV @ 7,869' L PERFORATION DATA 1 18 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft SPF Date Detail 10,627' 10,645' 10,413' 10,430' 18 6 7/11/97 2 -1/8" Enerjet H -1 ±10,629' ±10,647' ±10,415' ±10,432' 18 6 Future 3 -3/8" HC Guns V 9 ±10,659' ±10,685' ±10,443' ±10,468' 26 6 Future 3 -3/8" HC Guns - H -2 d 10,660' 10,687' 10,444' 10,470' 27 6 7/11/97 2 -1/8" Enerjet ±10,693' ±10,724' ±10,475' ±10,504' 31 6 Future 3 -3/8" HC Guns 1 H -3 0 10,695' 10,737' 10,477' 10,517' 42 6 7/11/97 2 -1/8" Enerjet 11 H -8 ±10,819' ±10,885' ±10,594' ±10,656' 66 6 Future 3 -3/8" HC Guns • Il_, Hemlock 10,822' 10,835' 10,596' 10,609' 13 4 9/13/1975 ■ 1 3 Hemlock 10,845' 10,884' 10,618' 10,655' 39 4 9/13/1975 112I 14 Hemlock 10,894' 10,910' 10,664' 10,679' 16 4 9/13/1975 v 15 / IN PBTD = 11,030' TD = 11,010' Revised By TDF 9/21/2012 Hole Angle = 25 °, KOP= 7,000' • • Swanson River AWS BOP — Williams 405 Rig 09/27/2012 11 i'. 5.00' 111 111 1111 111 111 • • 111 111 111 111 111 111 Iii 111 3.46' 14.21 Shaffer 11" 3M 111 111 111 111 111 Shaffer LVVS ,,„: 2.75' 11 "3M 2-1/16 10M Choke and Kill Valves 1.11 1i1 1i1 1i1 lil ■ 2.00' I{ : 1 mu 1�1III lit' - `ir : - 1�1 111111 III 111 1.00' August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue Anchorage, Alaska 99501 smrl'' \-1S�22-Z�- Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com b; 2609 lel*.Fk1 Oil &t r3a's C-grls, t rlrnrniRRIPP flear.hilI'agr l Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, (� 1 � CtAll Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase 1 Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct4 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life ` .0 t 7����++��11 AL,A�'r.S�HA OILpp,��77�, �ND�+ �+GLS CONS RVA ON C®l��i��i1SSION June 22, 2009 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 SCyANK Anchorage AK 99503 SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(a�alaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 _ Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 Trading Bay Unit D-40RD Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 Trading Bay Unit G-34RD Union Oil Company of California 168-038 _ Trading Bay Unit K-06RD _ Union Oil Company of California 169-066 Trading Bay Unit K-09 Union Oil Company of California 179-016 Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 Trading Bay Unit K-23 Union Oil Company of California 165-038 _ MGS St 17595 05 Union Oil Company of California 166-003 _ MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 _ MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 _ MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 _ Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 _ Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 _ Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 _ Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 _ Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN Union Oil Company of California 173-014 Trading Bay St A-30 • • Daniel E. Shier Consulting Geologist and Petrophysicist October 21, 2005 Jim Cowan Division of Oil and Gas 550 W. 7~' Ave., Suite 800 Anchorage, AK 99501 Dear Mr. Cowan: When the SCU 24-9 well was overlaid in the QC process years ago, it passed the test. Recently I have been made aware that the scales on the overlay copy were wrong. I have enclosed a corrected copy of this well. Please use it to replace the copy I sent earlier. Thanks, Daniel E. Shier 21538 W. 56~' Ave., Golden, CO 80403-8003 _ Email: eds(u~rockypine.com Web Site: www.rockypine.com /'~v -tea Phone: (303) 271-1538 FAX: Call before sending Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Williamson Drilling Manager September 10, 2001 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Tom Maunder Subject: Soldotna Creek Unit Well SCU 24A-9 APl No. 50-133-20273-00 10-404 Perforate G-Zone Dear Mr. Maunder: Please find enclosed in duplicate Form 10-404 for the perforation of the G-Zone in well SCU 24A-9. The following intervals were perforated on 3/28/01' Bench Top Bottom Feet G 10,564 10,590 26 G 10,610 10,620 10 If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, Dan Williamson Drilling Manager ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator Union Oil of California (Unocal) 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 2441' N & 2002' E from SW Cor. Sec. 9, T7N, R9W, SM At top of productive interval 1051' S & 75' E of surface location At effective depth 1099' S & 116' E of surface location At total depth 1105' S & 121' E of surface location 5. Type of Well: Development: X___ Exploratory: Stratigraphic: Service: 6o Datum elevation (DF or KB) 138' KB feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 24A-9 Permit number/approval number 75-22 0. APl number 50-133-20273 1. Field/Pool Swanson River/Hemlock & G-Zone 12. Present well condition summary Total depth: measured 11030 true vertical 10791 feet Plugs (measured) feet Effective depth: measured 11010 true vertical 10772 feet Junk (measured) feet Casing Length Structural Conductor 80' Surface 3395' Intermediate Production 9712' Liner 1511' Perforation depth: measured true vertical Size Cemented Measured depth True vertical depth 18" 80' 80' 10-3/4" 3395' 3395' Tubing (size, grade, and measured depth) 7-5/8" 9712' 9569' 5-1~" 9519'~11030' 9395'-10791' 1~564~-1~59~~~1~61~~~1~62~~~1~627~-1~645~~1~66~~-1~687~~1~695~-1~737~~1~822~-1~835~~ 10845'-10884',10894'-10910' 1~354~-1~379~~1~397~-1~4~7~~1~413~~1~43~~~1~444~-1~469~~1~477~-1~516~~1~595~-1~6~7~ 10617'-10653',10663'-10678' 3-1/2",9.2#, N-80from surfaceto 9409';2-7/8",6.4#, N-80from 9409'-10,517' Packers and SSSV (type and measured depth) Baker F-1 @ 10484', Baker FH @ 10804', 10837' & 10886'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production orlnie~ion Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure 7 4 338 760 11 3 550 950 Tubing Pressure 270 300 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: 16. Status of well classification as: Oil: X Gas: Suspended: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06/15/88 Title: ORIGINAL Date: SUBMIT IN DUPLICAT"E'-....~ UNOCAL ) RKB to TBG Hgr = 17.00' Cameron 3" Type "H" BPV Tbg hole @ 196' Probable Tbg hole @ 3082' DV @ 7869' 8 9 10 11 12 13 14 15 16 17 18 19 20 PBTD = 11030' TD = 11010' Hole Angle = 25°, KOP=7000' Swanson~'River Field Well # SCU 24A-9 Actual Completion 2/5/94 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 18" 104 Surf 80' 10-3/4" 40.5 K-55 Butt Surf 3395' 7-5/8" 33.7 P-110 Butt Surf 60' 7-5/8" 26.4 N-80 Butt 60' 4137' 7-5/8" 29.7 N-80 8rdLT&C 4137' 6061' 7-5/8" 33.7 P-110 8rdLT&C 6061' 9712' 7-5/8' Stage Collar @ 7869' 5-1/2" 20 N-80 9519' 11028' Tubing: 3-1/2" 9.2 N-80 AB Butt Surf 9409' 2-7/8' 6.4 N-80 Butt 9409' 10517' 2-3/8" 4.6 10771' 10911' JEWELRY DETAIL NO. Depth Item 1 17 2 9409 3 9444 4 10484 5 10506 6 10517 3-1/2" 8rd tbg hgr, 8rd x butt xover 3-1/2" x 2-7/8" butt xover Camco 2-7/8" KBMG 1" glm with 5/16" orifice valve, 1/27/97 Baker F-1 packer, 2-7/8" x 5-1/2" Otis "X" nipple, 2.313" ID 2-7/8" Tbg tail (mule shoe re-entry) 7 10771 8 10801 9 10804 10 10811 11 10812 10832 12 10834 13 10837 14 10843 15 10844 10882 16 10883 17 10886 18 10892 19 10893 20 10911 TOP BTM 2-3/8" re-entry guide 2-3/8" Otis "XA" sleeve 2-3/8' x 5-1/2" Baker FH packer Otis "S" nipple position 4/3 One 2-3/8" blast joint Brown "CC" safety joint Otis "XA" sleeve 2-3/8' x 5-1/2" Baker FH packer Otis "S" nipple position 4/2 Two 2-3/8" blast joints Brown "CC" safety joint Otis "XA" sleeve 2-3/8' x 5-1/2" Baker FH packer Camco 2-3/8 .... D" nipple w/plug set in 9/77 (Unable to pull plug with several attempts) One 2-3/8" blast joint Baker 2-3/8" shear out sub PERFORATION DATA ZONE SPF DATE COMMENTS 10822 10835 10845 10884 10894 10910 10695 10737 10660 10687 10627 10645 10610 10620 10564 10590 Hemlock 4 9/13/75 Hemlock 4 9/13/75 Hemlock 4 9/13/75 H3 6 7/11/97 H2 6 7/11/97 H1 6 7/11/97 G 6 3/28/01 G 6 3/28/01 REVISED: 9/7/2001 DRAWN BY: TAB STATE OF ALASKA ALA<_. OIL AND GAS CONSERVATION C°M -'--'°NTIERA REPORT OF SUNDRY WELL OP ONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing _ _ Alter casing__ __ Plugging _ _ Perforate __ Repair well __ Pull tubing X_ Other_ _ 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development X_ Exploratory __ Stratigraphic___ Service ---- 4. Location of well at sudace 2441' North and 2002' East of SW Corner of Sec. 9, TTN, R9W, SBM 6. Datum elevation (DF or KB) 138' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SC U 24A- 9 At top of productive interval 1051' South and 75' East of surface location At effective depth 1099' South and 116' East of surface location At total depth 1105' South and 121' East of surface location ORIGINAL 9. Permit number/approval number 75- 22/93 -318 10. APl number 50-133 - 20273 ' 11. Field/Pool Swanson River-Hemlock feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,030' feet Plugs (measured) 10,790' feet 11,010' feet Junk (measured) 10,772' feet Casing Length Size Structural Conductor 80' 18" Surface 3395' 10-3/4" Intermediate 9712' 7-5/8" Production 1511' 5-1/2" Liner Cemented PefforaUon depth: measured 10822'-10825'; 1 0845'-10884'; 10894'-10910' Measured depth True vertical depth 80' 80' 3395' 3395' 9712' 9569' 9519-11030' 9395'- 10791' true vertical 10595'-10607'; 10617'-10653'; 10663'-10678' Tubing (size, grade, and measured depth) See Schematic Packers and SSSV (type and measured depth) See Schematic 13. Stimulation or cement squeeze summary Intervals treated (measured) None Treatment description including volumes used and final pressure None R£C£1VED ^o~) 1 1 lqq~, · ' ' '~ ~ ' Gas Oons. Commissio~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Shut in Oil producer 102 13,004 180 1020 Tubing Pressure 2850 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations x _ 16. Status of well classification as: Oil x_ Gas __ Suspended _ _ Service Form 10-404 Rev 06/15/88 and correct to the best of my knowledge. Title Drilling Manager Date 04/04/94 SUBMIT IN DUPLICATE.. SWANSON RIVER FIELD 24A-9 ACTUAL 3/10/94 10 3/4" 40.5# K-55 @3395' GAS LIFT MANDRELS AS DETAILED TOP OF 5 1/2" @9519' ? 5/8" 33.?// ~ P-110 BUTRESS @9712' PERFS FROM 10,822'-10,835'1 PERFS FROM 10,84,5-10,884' / PERFS FROM 10,894-10,91 O' ~[ 5 @11,030' (TD) 8 ? 8 9 10 11 13 14 15 18 I? 18 uO A) 3 l/fi' 9.2# N-80 BT @9409' (290 JTS) B) 2 7/8" 6.4# N-80 BT TBG (35 JTS) 1) BAKER F- 1 PKR W/SEALBORE EXT. @10,484' 2) 10'2 7/8" 6.4# PUP @10,496' 3) OTIS "x'' NIPPLE @ 10,506' 4) 10'2 7/8" 6.4# PUP @10,507' 5) WIRELINE RE-ENTRY GUIDE @ 10,517' 6) 2 3/8" TBG PC W/WIRELINE RE-ENTRY @10,771' 7) 2 3/8" OTIS "XA" SLEEVE @10,802' 8) BAKER ' Fff' PER @ 10,804' 9) OTIS "S" NIPPLE @10,811' 10) 2 3/8" BLAST JT @10,812' 11) 2 3/8" BROWN "CC' JT @10,832' 12) 2 3/8" OTIS "XA" SLEEVE @10,834' 13)BAKER 'FH" PER @10837' 14)2 3/8" OTIS "~' NIPPLE @10,843' 15)2-2 3/8" BLAST JTS @10,844' 16) 2 3/8" BROWN "CC" JT @10,882' 17) 2 3/8" OTIS "XA" SLEEVE @10,883' 18) BAKER 'FH" PER @10,886' 19) 2 3/8" CAMCO "D' NIPPLE @10,892' 20) 2 3/8" BLAST JT @10,893' 21) 2 3/8" BAKER SHEAROUT SUB @10,910' PBTD @ 11,010' SCU 24A-9 DAY 1 (01/19/94) RIH W/IMPRESSION BLOCK. FOUND SAND ON TOP OF PLUG. RI W/SWAB BAILER. BAILING SAND FROM TUBING. GOOD SAND RECOVERY IN BAILER, BUT NOT MAKING ANY HEADWAY IN WELLBORE. MOVING RIG & RIGGING UP ON LOCATION. DAY 2 (01/20/94) MOVE RIG FROM 21A-34 TO 24A-9 AND RIG UP. MADE SIX BAILER RUNS RECOVER PEA GRAVEL, SCALE AND SAND, CLEAN FROM 10781' TO 10786'. DAY 3-5 (01/21-23/94) ACCEPT A RIG AT 2:00 HRS ON 10/21/94. CIRCULATE DOWN TUBING AND UP ANNULUS PUT TRACER IN BRINE TO CONFIRM CIRCULATING FROM HOLES AT 10781'. BAILED SAND FROM 10774' TO 10806' WLM. COULD MAKE NO PROCESS. R/U COIL TUBING WASH FROM 10805' TO 10810'. RETREIVE PLUG AT 10810' DPM W/W.L. KILL WELL. SET PLUG N/D TREE. N/U BOP A']-i'EMPT TO SCREW IN LANDING JOINT, THREADS IN HANGER BAD. TEST BOP. DAY 6 (01/24/94) RETRIEVED TUBING PLUG CUT TUBING AT 107' USE SPEAR TO RETRIEVE HANGER AND TUBING. RUN NEW HANGER COMPLETE BOP TEST. ATTEMPT TO PULL HANGER STUCK IN TUBING HEAD. JAR HANGER FREE. RIH W/O.S. LATCH TUBING PULL TO 55K LBS. TUBING PARTED. POOH RECOVER 4100' OF TUBING PINS VERY CORRODED. BOX LOOKING UP. DAY 7 (01/25/94) RIH W/TUBING LATCH. TUBING FISH AT 4269'. P/U TO 64K TUBING PARTED. POOH. RECOVER 11 JOINTS OF TUBING PINS BADLY CORRODED. RIH TAG TIGHT SPOT AT 4592'. LATCH FISH AT 4607'. MADE W.L GAUGE RUN TO 9300'. DAY 8 (01/26/94) CUT TUBING AT 6526'. POOH L/D 60 JTS OF 3-1/2" TUBING TOF 6519'. RIH LATCH FISH COULD NOT GET PAST 9378' W/CU'I-rER FOR 2-3/8" T_UI~JN~, (JUNK AT THIS POINT). ~ ~ C ~ ~V~ ~ Gas Cons. Commission Anchorage DAY 10-12 (01/28-30/94) 10-3/4" @ 3395' 7-5/8"@ 9712' 5-1/2" LINER @ 9519'-11030' POOH. FOUND 5 CUTTER KNIVES BROKEN. REDRESS CUTTER. RIH ATTEMPT CUT AT 9389'. POOH, CUTTER HAD MALUFUNCTIONED, NO CUT MADE. RIH W/5-3/4" OVERSHOT W/3-1/2" GRAPPLE. LATCH FISH ATTEMPT BLIND BACK OFF. PIPE BACKED OFF IN 3-1/2" TUBING WORK STRING AT 5500'. SCREW BACK INTO PIPE. RELEASE O.S. POOH. RIH W/HOMCO HYDRAULIC CUTTER. ATTEMPT OUTSIDE CUT AT 9398' NO SUCCESS. POOH. FOUND 5 KNIVES BROKEN. RIH W/TRI STATE MECHANICAL CUTTER MADE OUTSIDE CUT AT 9450'. DAY 13 (01/31/94) 10-3/4"@ 3395' 7-5/8"@ 9712' 5-1/2" LINER @ 9519'-'11030' POOH AND RECOVERED 79' OF CORK SCREWED TUBING. RIH W/OVERSHOT LATCH FISH AT 9450' ATTEMPT TO RUN CHEMICAL AND JET CUTTER. COULD NOT PASS 9528'. RIH W/STRING SHOT BACK OFF TUBING AT 10677'. DAY 14 (02/01/94) 10-3/4"@ 3395' 7-5/8"@ 9712' 5-1/2" LINER @ 9519'-11030' POOH L/D FISH. TEST BOP'S. RIH W/OVERSHOT LATCH 2-3/8" TUBING AT 10661'. ATTEMPT TO CIRCULATE THROUGH HOLES IN TUBING. CUT TUBING AT 10,764' WLM. DAY 15 (02/02/94) 10-3/4" @ 3395' 7-5/8" @ 9712' 5-1/2" LINER @ 9519'-11030' CIRCULATE BOTTOMS UP. POOH W/TUBING FISH. RIH W/OVERSHOT AND RE-ENTRY GUIDE ON SCRAPERS. SET OVER SHOT OVER STUB WITH RE- ENTRY GUIDE AT 10,754'. POOH. RECEIVED i~.i~s~. Oi~ & Gas Cons. Oommissio¢, A,,~chorage DAY 16 (02/03/94) 10-3/4" @ 3395' 7-5/8" @ 9712' 5-1/2" LINER @ 9519'-11030' POOH L/D SCRAPERS. RIH SET RI-i'S AT 4727 TEST CASING TO 3000 PSI. RIH TO 9452' TEST CASING TO 3000 PSI 7-5/8" CASING OK. POOH. RIH W/GAUGE RING AND JUNK BASKET TO 10650'. POOH. DAY 17-18 (02/04-05/94) 10-3/4" @ 3395' 7-5/8"@ 9712' 5-1/2" LINER @ 9519'-11030' SET BAKER SAB PACKER AT 10480' WLM. RUN COMPLETION, HYDROTESTING STRING TO 5000 PSI. LAND COMPLETION, TEST ANNULUS TO 3000 PSI. N/D BOP. N/U TREE. TEST TO 5000 PSI. RELEASE RIG TO SCU 21A-4 AT 1400 HRS ON 2/5/94. Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA-~,L AND GAS CONSERVATION CC ilSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Suspend __ Alter casing__ Repair well __ Change approved program __ 2. Name of Operator Union Oil Company of California dba Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 Operations shutdown __ Re-enter suspended well Plugging __ Time extension __ Stimulate Pull tubing X Variance 5. Type of Well: Development Explomton/ Strafigraphic 4. Location of well at surface 2,441' North and 2,002' East from Southwest Corner Section 9, 'I'TN, R9W, Seward B&M Perforate Other 6. D--atum elevation (DF or KB) 138'K.B. 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 24A-9 At top of productive interval 1,051' South and 75' East of Surface Location At effective depth 1,099' South and 116' East of Surface At total depth 1,105' South and 121' East of Surface 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,030' 10,7901 RECEIVED l~!OV 1 8 ~333 ~,::!~ Oil & C~ ~on~. C,~mrnissi0n Ar~h0ra~e feet F~ugs'(measured) feet 11,010' feet Junk (measured) 10,772' feet 9. Permit number 10. APl number 50-133-20273 11. Field/Pool Swanson River-Hemlock feet Casing Structural Conductor Surface Intermediate Production Liner Length 80' 3,395' 9,712' 1,511' Perforation depth: measured Size Cemented Measured depth True vertical depth 18" 80' 80' 10-3/4" 3,395' 3,395' 7-5/8" 9,712' 5-1/2" 9,519'-11,030' 10,822'-10,835', 10,845'-10,884', 10,894'-10,910' 9,569' 9,395'-10,791' true vertical 10,595'-10,607', 10,617'-10,653', 10,663'-10,678' Tubing (size, grade, and measured depth) See Schematic Packers and SSSV (type and measured depth) See Schematic 13. Attachments Description summary of proposal X__ Detailed operations program__ BOP sketch X 14. Estimated date for commencing operation 115. December 26, 1993 16. If proposal was verbally approved Oil X__ Gas Name of approver Date approved Service 7. I her.eb¥ cer/13fy that th~for/eg.o{ng is tru~ and correct to,he best of my knowledge. ~C / ~-~', . Signed / FOR COMMISSION USE ONLY Status of well classification as: Suspended __ Conditions of approval: Notify Commission so representative may witness Plug Integrity ~ BOP Test Mechanical Integrity Test_ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form required 10- ~ cci Original Signea By David W. Johnston J Approval ~ ~._ ~~ ~pproved Copy Returned ir- -z,,-t.-/"~ Cb~miSsioner -D-~te ¢'11~I ¢~ SUBMIT IN TRIPLICATE Swanson River Field SCU 24A-9 Workover Procedure II II IIII 1. Set plug in S Nipple @ 10,810.' 2. Rig up electric line and jet cut tubing @ 10,780'. 4. Kill well. 5. Nipple down tree and nipple up B.O.P. Test B.O.P. to 5,000 psi. 6. Pull out of hole laying down tubing. 5. Release top packer and POOH. 6. RIH with gauge ring and junk basket to 10,822.' 7. RIH with completion string 8. Pressure test tubing/casing annulus to 1,500 psi. 9. ln~all BPV; nipple down B.O.P. Nipple up tree; pressure test to 5,000 psi. 10. Release Rig. RECEIVED Ar~chorage Swanson River Field SCU 24A-9 Proposed 11/16/93 10-3/4' 40.5# K-55 @ 3,395' Top of 5-1/2' @ 9,519' Gas Lift Mandrel as Specified 3-1/2" 9.2# N-80 Butffess @ 9300' 7-5/8' 33.7# P-1 lOButt~ss @ 9,712' 2-7/8' 6,4# N-80 Butbess Peffs: ' 0,822'-10,835' Peffs: I 0,845'-10,884' Peffs: 10,894'-10,910' PBTD @ 11,010' 5-1/2"20~ N-80 @ 11,030'(TD) Downhole Jewelry t, Bakel Model F- 1 Packer @ 10,600' (set to allow future perfs @ 10,660') 2, Seal Bore Extension 3. 10,'2-3/8' Pup Joint 4. X-Nipple 5. 10,'2-3/8' Pup Joint 6, Wileline Re-ent~y Guide 7, Peffs @ 10,822'-10,836' 8, Wireline Re-enffy Guide 9. Blown CC Safety Joint @ 10,832' 10, Offs XA Sleeve @ 10,833' 11. Baker FH Packer @ 10,836' 12, Otis S-Nipple @ 10,842' 13, Two 2-3/8' Blast Joints 14. Brown CC Safety Joint @ 10,881' 15, 2-3/8' Otis XA Sleeve @ 10,883' 16, Bake~ FH Packel @ 10,886' RECEIVED :~,~ ~..:~i & 6as C0r~s. COfflITIiSsiorl Anchorage t 6061' ! · ' K.B. TO LANDXN O ~LKD~ · · -- ..... Tubing llanger ?b ars.3%' ~.J/£ug ~rd ~-~0 . . . . ~,~.0~' ~ ~CO ~ ~AND~' ., ' ' I~. ' ~am.~.~l ] . 7 d~S.'~ 9.31 / ' "J 37 J~. ~'9.31 Ir.C. ti .. 1.00, 9,10' 1693.07' ~28J.67, 9.81' 1016.2~' 9.6J' 9,72' b63,39' . 9.~' 9.X2' I ~6 ,ITS, 2~, b;71 gUI: 8rd ~1-80 ?UBXI~3 ].426.82, · · · · · , · · · TOP OI - R/O 'l~' 11,0~0, 2.88, 6.15' 1. %2 ' 2o;ja, 2.88' 6,X7' 1.%2' 2,8~t 6,x6' 2.7.00, e II ii i i i · i ::.: i SCU24A-9 CASING & TUBING DETAIL ' SECTION ~ 'r, 7N,, R, gW, Con[fao[ Exhibi[ E OPTION 1 FILL-UP NILL LINE ANNULAR BOP 10" 3000 psi PIPE RAMS 10" 5000 psi BLIND RAMS 10" 5000 psi [T~L,/[~'-~T- SPOOL ~~,/[[P'~,'~ 5000 psi ii t 3" 5000 I [ PIPERAMS ] 10" 5000 psi I FLOW CHONE LINE psi BOP STACK 10" 5000 psi R£C£IV£D Gas Gens. Commission Anchorage Alaska Region Unocal North American 7~ ~-'~ Oil & Gas Division Unocal Corporation P.O, Box 190247 ..~¢~- ~-OMM- "~ Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 ~(~MM C~OMM RcS ENG UNOCAL "" SR ENG /'~,~ ,/~ ~. 4- ~v' ~.. ENG-AssT-'I--I ~NG ASST March 24, 1993 ~~/~ SR GEOL I I -~-EOL ASSTI ; '~EOL ASSTI, ~TAT TECHI _~ FILE Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in S.,.wans0n:,RiverField~ Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RECEIV'ED MAR 2,5 199;5 Alaska 0il & Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company Yours very truly, Petroleum Engineer RECEIVED' MAR 2,5 199,~ Alaska 0il & Gas Cons. Commission Anchorage Form 31604 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS FORM APPROVED Budget Bureau No. 1004-O135 Expires: March 31,1993~ 5. Lease Designation and Serial No. 6. If Indian, Allonee or Tribe Name Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals SUBMIT IN TRIPLICATE i. Type of Well [ Oil Gas 2. Name of Operator Union 0il Company of California (dba Unocal) 3. Address and Telephone No. P. 0. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit 17 wells Soldotna Creek Unit-- 14 wells (907) 276-7600 12. TYPE OF SUBMISSION TYPE OF ACTION 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8, Well Name and No. 9, APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field !1. County or Parish, State Kenai ~ Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA [~ Notice of Intent ['--] Subs~uent Report '-']Final Abandonment Notice --]Abandonment F'-I Recompletion ]]Plugging Back F"] Casing Repair F"] Altering Casing [~] Omer Temporari 1 y Abandon [~] Change of Plans '"']New Construction ~-] Non-Routine Fracturing [~] Water Shut-Off r-]conversion to Injection r~ Dispose Water (Note: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starling any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' Swan SCU 21-3 SCU 23B-3~ SCU 13-4 SCU 21A-4 SCU 34-4~ SCU 43A-4 SCU 33-5 son River Unit SCU 21-8*/°~ SCU 243-8F SCU 341-8~ SCU 13-9/ ~SCU 24A-9'~ SCU 34-9'~ SCU 14-34u' Swanson River Unit SRU 212-10 ~ SRU SRU 14-15' SRU SRU 23-15/ SRU SRU 34-15 SRU SRU 41A-15~ SRU SRU 43A-15 SRU SRU 432-15 SRU SRU 14-22~ SRU SRU 23-22 ~ 23-27~ 212-27~ 331-27 34-28 ~ 43-28 ~ RECEIVED 24-33" 32-33WD ~ N~AR ~ 5 1~ Alaska 0il & Gas Boris. Gom~s~,Or--~ Anchorag~ * High G0R wells that may be produced intermittently. 14. I hcrcby certify that~forcgoingA~c~_ ~o~rr~t..~,, ~..,,, ~ Petroleum Engineer Date Approved by Title Date Conditions of approval, if any: Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any depamnent or agency of the United States any false, fictitious or fraudulent statements *See Instruction on Re. me Sid~ Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Rate Potential P & a Shallow Gas Potential and 'Hemlock Only' P & A Shut-in Wells until the Field Blowdown Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 7 Wells 3 Wells 5 Wells SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9" SCU 23B-3" SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33c2~ 5 Wells Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 Scheduled 'Hemlock Only' P & A in March-April, 1993. High GOR wells that may be produced intermittently. RECEIVED Anc/]orag~ Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. · SCU 21-3: Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: Returned to production after fiowline repair. · SRU 12A-4: Returned to full time production in 1992. · SRU 211-15 Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR ~ 5 ~99;5 Alaska Oil & Gas Cons. oorr~missto~' Anchorage Form 31~,0-5 (November 1983) (Formerty 9.33Z) UNITED STATES (Oeher in4truetJome DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not uJ~ thl. for,- for propo~ls to drtli or to dentsu or plug back ~ i dJEer~at ree4rvolr. Uo~ "ApPLICATION FOR PERMIT--" for such propose&) oft,, I'~ Form approved. Budget Bureau No. 1004-0I.]5 Exoires Au~st 31. 1985 ~. I.~AlJl I)SIIO~ATIOW AND IBalaL WO. ~. ii' IIOIAI. ALr, OTTI! O! TRill NAME NAMB 01' OfiaAX~)l 3. Am>ir, mm Of OPUATOB 14. pIaMIx NO. Soldotna Creek/Swanson Rv 8. fd, BM OB LI&II MAMI P.O.Box 100360 Anchoraqe, AK 99510 UmCATZON or u roLL (Remmrt Iocatioa clearly end tn Accordance. with may S~ r~utremen~· At 8u~l~ I15. I~VA~O~a (S~ wb~er Dff. ~. ~ ~) 10. fflBLO AND P~OL) OI WILD~AT Swanson R±ver F±eld ll. ~B~., '1% I. ]lq OB aLE. LIrD 12. ~ot2~T om I,&tml IL 8T&"rm Kenai Alaska 16. Check Appropr, ate Box To Indicate Nature of Notice, Report, or Other Data NO~lCl Oil IN~BNTION TO: (Otb,) Temporary Abandon '1'-~. o~scafag PROPOSED OI coMrLETEO OrZasTtO.XC. (Clearly state all ~rtluf.t detatla, and =ire ~rttneut dat~ lnelud~ mflml~ ~M ~ I~ ~y p~ wor~ If MI b di~fion~y dhll~ gi~ ~~ ~unn and meaour~ iud t~e ,ertl~ dep~ tar ~ ma~em ~d MRN ~- · nen~ m ~h ~L) · As decribed in the attached memo, ARCO Alaska, Inc. requests that the following wells have a temporarily abandoned status: ~oldotua Creek Unit SCU 23B-3 SCU 21-8 * SCL/ 12A-4 SCU 341-8 SCU 13-4 SCU 13-9 SCU 21A-4 SCI./ 24A-9 SCU 34-4 SCU 34-9 SCU 43A-4 SCU 14-34 SCU 3~5 Swan~n River Unit SRU 212-10 SRU 1 4-15 SRU 23-15 SRU 34-15 SRU 211-15 SRU 41A-15 SRU 43A-~5 SRU 432-15 SRU 14-22 SRU 21-22 SRU 23-22 SRU 23-27 $RU 212-27 $RU 331-27 SRU 34-28 $RU 43-28 SRU 14A-33 SRU 24-33 SRU 32-33WD * -High GaR wells that may be produced intermittently. 18. I hereby ce~fy-~at ~he fo~refoLnf ia trde and corre~ RECEIVED DEC 5 7 199{ Alaska 0il & Gas Cons. C0mmis TXTLE Actinq Reqional En_.qineer (Thio il)act for Federal or APPROVED BY CONDITIONS OF APPROVAL, Ir ANT: TITLE DATa *See Inmucfiom on Reverse Side Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock :!:~:i:i:i:i:!:i:i:i:i:i:i:i:i:!:i:~:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:!:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:~:i:i:~:i:i:i:i:i:i:i:i:i:i:i:i:~:!:i:i:i:i:i:i:i:i:!:i:i:i:i:i:!:i:i:i:!:!:i:i:i:i:i:i.i:i:i:i.i:i:i:i:i:i:!:i:i:!:i:!.i:i:~:!:i:!.i SCU 12A-4 SRU 212-10 SCU 13-4 SRU 211-15 SCU 21A-4 SRU 23-15 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 SRU 32-33WD SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 9 Well~ 3 Wells Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned ~:i:i:i:~:i:~:~:i:i:i:i:~:i:i:i:i:i:i:i:i:~:i:i:i:i:~:i:!:i:i:i:i:~:~:~:i:i:~:~:i:~:i:i:i:!:i:i:i:i:~:i:~:~:~:~:i:~:~:!:~:~:~:~:i:i:i:i:i:~:~:i:i:i:~:i:!:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:~:i:i::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::i:::i:i:i¥..:::~i SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For. Temporarily Abandonment Sundry 12/27/91. Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) RECEIVED Alaska Oil & (~as ¢o~s. ¢ommis~ ~c~orage Added to 1992 Temporarily Abandoned Status: SCU 23B-3 & . · SCU 21-8: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. · SCU 12A-4: High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdoWn. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well currently shut-in due to problems with the towline. Well will be' returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU 21-15 & · SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED DEC 5 1 199l Alaska Oil & Gas Cons. uummissiol, Anchoraoe ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 iST_AT TECHI [ Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry. Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: o rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC ~ 1 199t Alaska 0il & Gas Cons. CommiSSiOn Anchorage Mr. ~. A. Dygas Page 2 December 27, 1991 Shut-in wells until field blowdown, including:. e Hemlock producers, and wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye~ar's TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4107. Sincerely, J. C. W inn Acting Regional Engineer JTZ:jlg:0025 Attachment CC:. L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation RECEIVED Alaska Oil & Gas Cons. Anchora~le 7'/o F..F,~ I ~ 1'978 DIVISION Ot SUBMIT IN DUPL~'~'~ATE STATE OF ALASKA < See other In- st ructions on 01/ AND GAS CONSERVATION C08MITTEE ~L III II I I WELL COMPLETION OR RECOMPLETION REPORT AND LOG* .~,~, , ~ ' TYPE 0F W~LL: ozl, u~s wEI. L WELL ~ DRY Other b, TYPE OF COMPI.E~ON: XV EI.I. ()VER EN BACK gESVR. Other 2. NAM E ()P OPKRA'I'OI~. Standard O±1 Company of Californiar WOI ADDRESS OF OPERATOR P. 0. Box 7-839~ Anchoraqe, Alaska 99510 4. Lo(:,'rmx ur w~:Lb (Report location clearly and in accordance with a~y State requirements)* xt ~u~f~c~ 2441' North and 2002' East from the Southwest corner of Section 9, T-7N, R-9W, SB&M At tnp prod. interval reported below At tota~ aeV~ 1245' South and 24' West of surface 13. DA_TE S['UIIDtiI) DATE T.D. RE, ACHED {15. DATE' COMP SUSP O1~ ABA,N-I). 8/12/75 5/22/75 t-~OW i~iANY* ROTARY TOOLS 11056 MD 10786' TVD 9921' MD 9756' 0-11056 '>'.2. PRODUCING !NTEHVAL(S;, OF THIS COMPLETION--TO,P, BOTTOM, NAME (MD AND TV]i})* nr glNAL 5. API ~C~L, CODE ' 50-133-20273 6. LEASE DESIGNATION A2ND SERIAL NO. A-028997 7. IF INDIA_N, ALLOTTEE OR TRIBE NA2~IE 8. UNIT,FA/tM OR LF~kSE NAME Soldotna Creek 9. WELL NO. SCU. 24-9 10. FIELD AND POOL, OR WI~C&~ Swanson River - Hemlock 11. SEC., T., R., ~., (BOTTO~ O~IVE) Sec. 9, T-TN, R-9W, SB&M 12. P~{IT ~O. 75-22 8/22/74 138' ~ INTER%'AL8DRILLED BY CABLE TOOLS 0 23. WAS DIRECTIONAL ~ SURVEY ~ADE Yes 24. 'Fi't'k; ILL,E("Fi',IC AND OTIIEiq. LOGS RUN D1L, BCS 25. CASING RECORD (Report all strings set in w'ell) ' WEIGHT, LB, FT. 1} Gi~ADE ..... !! DEPTH SET59,(NLD) HOLE SIZE ] CE.%ILNTING RECO?J~ Il £~.qOUNT PULLED 18~', 10'3/4" 7 5/8- 4'0.5 126.4, 29.7 33.7 28. I , , 30. K-55! N'-80 t ,. r-l,,io/ 3395' 9712" Driven t None 15"i[1300 sks. cmt None 9 7./8" Shoe - 240 sks~ st, age None collar 7,.8,69' - 620 sks 27. TUBING REC OC~D TOP (),'ID} '' ' ~fAID [ DEPTPI SET (AID) PACt(ER SET (~/iD) OPEN TO PRODUU'IION (interval, size and number) 29, YACID, Si!CT, Ff1A7~ 0-RE, C~&ENT SQUE~, ETC. D~2~i 1NT~V.~ (MD) ] AM. CUNt 2~D I'2!ND OF A(~7'EP~AL US~ i i ii i ii i1 PI~ODUCTION DA'r~:; ~;'t;~s;t' ['~:~DUCTION I P~ODUCIqON MEZ[{OD (Fmwh~g, ~:a3 nf~, pamp~ng~size and type of pump~ iX~:~LL ~TATUS (Producing or ~K~3~oned below 9921' DATE OF T~ST, ~iUURS EST~ Ct!OKE SIZE OI~BEL. GAS--SiCF. %Vf~TER--BBL. GAS-OIL ILkTIO CALC~T~ OI~BBL. GAS--LICF. WA~BBL. ~ OIL GRAVITY-~I (COR~.) 1 FLOW, 'L'U£iINC; UASI. NG PRESSURE 31. pmposl'rloN or c,,s (,gold, used ]or ]uel, vented, etc.) 32. I.IST OF ATTACHMENTS WITNESSED BY D1L, BCS · 'available recof¥~ . /' 7;2 I hereby certify that the foregoing and atta/~d/Jnfor~f~tlon is comPlet~ and correct as determine~l from all SIC;NED R. M. MeK~ ITLE ~'r'o~ ~..ncr-l~,--~,-v- DATE I III I I I II II I *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for subm~ttin9 a complete and correct weil completion report er~d all types of lands and leases in Alaska. Item: 16: indicate which elevation is used as reference (where not otherwise sho,,,.'~) for depth measure- merits given in other spaces on this form ancl in any Items 20, and 22:: If this well is completed for separate production from more th,~n one ~nterval zone (multiple completion), so stale ~n ~tem 20, and ~r~ ite'*~ ?? show the prc.:Juc::',.~l interval, or ~,~tervals, lop(s), bottom(s) and name (s) (if any) for only the interv,~! reported in iten~ 30. Submit 'a separate report (page) on this form, adequately identified, for each additior~al ir~te~val to be separately produced, show- ing the ac}ditionat data pertinent to such ~nterval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing anct the location of the cementing tool. Item 28: Submit a separate completion report on this form for each nterval to be separately produc~.d. (See instruction for items 20 and 22 above). 34. SUMMAIt¥ OF' I~O}{MATION TF_,S'I','~ 1N('LUI)IN(; INI'~,RVAL TF_,STED, t~HE~$UHE DAT~ ~ ECOVERI~ OE OIL GAS. 35 G~GIC MARK~q WAT~ AND MUD ~ , M~AS. ~ ~U~V~T. ~: , ,, , ,, SUBMIT IN DUPL- TE*.. -~$TATE OF ALASKA .~t r%iCt IOH.~ rev~r~ OIL AND GAS CONSERVATION COMMITTEE II I ~ II i i i i i i i . _ . i i WEL'L COMPLETION OR RECOMPLETION REPORT AND LOG* "~Is. TY~E 6~" WELL: ' .... ua,' ~ ~ ~ W~LL W~LL ~ P~ ~ Oth~r ~ TYPE OF ~z- X o,'z.w°"'; ~ z~"~' ~ ..,e,~"c~ ~ ,,rr.nzs,.,.~ other Sidetrack WELL , ~. NAM~ or uP[RATOR 5~a~ O~Z Com~y o~ CaZ~O~n~ar ~OT 4. I. OC~T~ON 0¥ WELL IReport location clearl~ and in accordance w:th any State requirement.)* at ~u~ae, 2441' HarSh and 2002~ East from ~e Souehwes~ co.er of · Section 9, T-TH, R-gw, At top ~roa. laterval rep0rtea below ~06~~ Son~h and 79' Eas~ of surface locae~on. At total d~p~ . 1115' Sou~h and 126' Eas~ of surface locaeion D,LTE SFUDDED 114. DATE T.D. RF~tCHED 8/23/75 I 9/7/75 'feTAL DEk~rH. 5LD & TVD 15. DATE COA~P SUSP 9/16/75 138' KB 9. PLUG, BACK MD & T'v'D~0. 1F .'VIULTZPLE COSI. PL.. [ 21. 11030 ' MD 10790 TVD ! 11010t MD 10771 ' TVD ~ ~ow ~u~NY. ] 0--11aOTaa~iTOOLS'030' m. eRODUCn~O :N~W^L(S,. OF TInS CO.~eUmt~O.W--TO~. SOrrOM. ~a~m (~ ^.w~ Top 10822' MD 10594' TVD Hemlock Bottom 10910'MD 106.77 ;' TVD A'PI NUALLR/CAL CODE 50-133-20273 ~. LF-&~E DESIGNATION A. ND SEALOL NO. A-028997 ?. IF INDLA.N. ~TT~K OR TRIBE NA. ALE 8. UNIT,FA/~M OR LF.A~E Soldotn. a Creek g. WELL NO. SCU 24A-9 10. FIELD &ND POOL, OR %viI,DC&T Swanson River - Hemlock ii. SEC.. T.. Il...M.. (~OTTOM O~ECTIVE ) Sec. 9, T-7N, R-9W, SB&M 75-22 ~V~TIONS {DF, I{KB. R'I', GR, ~C)' ~17. ~V. CASINGtfEAD I INTERVALS DRILLED BY " CABLE TOO[ 0 ~. WAS ~ SURVEY MADE { Yes CA. SI~iC; SIZE ~' 18" .... 10"'3/4" ~ 7 5/8" ~4. TYPE ELECTi,.IC kND OTHEK LOGS RUN · D1L, BCS, Proximity -Midrolog, FDC, CNL, Cement bond log - ' I~ECOR'D ' ' C^SING (Ruport a~[ strings set tn ~ WEIGI{T. LB ~T. ~[ GmkDE } DL~{ SET (~m, ~ HOLE StZfZ~6.4,33.740.529 7, N-80p_i10K-55..Ii 9712t33955~'i .... . DrivenCESILNTING RECO}~ i /C.[OUNT PULLEDNoneNOne LIN E.-t RECO }kD I SkC'KS CE3.1EN~T' $IZD [ TOP (2.ID, EOI'T05I ,5ID, '46 cU. ft 15" [1300 sks. cmt 9 7.,/8" Shoe - 240 sks, sta~e None lcollar 7869' "- 620 ,~ks I2 'I' TUBING Se~ ~ched A~tD. St.CT. F.i.%2'q Ci~, C~.ILN~ SQL'L~Z2. ETC. i 10822' - 10910' four 1/2;', jet holes per foot. . · I 30. PILODUCTION DA'£E FIF,~T PIIODUCTION 9/17/75 DA'~~' or TEST. 9/17/75 FLOW, TL'EING 180 ht.;URS q ES'FED 4 ,CAS LN C, PRESSURE CIIOXE SiZE Iq'E.~I' i'i~H.'.OD CA t,CULATED OIL---L: Bi. 1217 FF, ODUCTION 51LL[{OD ~Fi.)v.'/,'g. [.'aa ltl~. pampLng--size and type of pump, Flowing OIL--UDL. 203.83 I 119 ~|. VI,~POSlIION Or (;iS t,.'~Old, u,ed ;or/.,el, t'¢ntcd, etc.) Injected back into field 32. tlsl ur Tubing Detail, D1L, BCS, Proximity- Microlog, FDC, CNL, Cement bond. ..... and atj~e.,)/ i,dyA'/mat{,,u 1. compl~t~ and correct a~ det~rmi,,t-d /r~m all ~(:allable SI~5'Et,: R. M- McKinley. TITLE ~ gineer DATE -- J _ Il ii ......... I I *(See Instructions and Spaces for Additional Data on Reverse Side) General: This form is designed for submitting a complete aneJ correct~ wetl completion report end log on all types of lan:is and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in c~her spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state ~n item 20, and in item 22 show the p~cJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only ~he interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ack..Jitional data pertinent to such interval. It~m2~: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any 'mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). WATEJ~. AND MUD . . i ,,, ,, ,,,, ~a. r'oa~ ~aTa. a~'rac~i nm~~mcm~mo~s .......... or ~T~ouoav, ~ono~i:TV, , - AND I)E'I'EC~'EI) SII()WS OF OIb. GAS .. i , ii _ · ........ _ GR[AT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY $~A~DARD OIL COI~PANY COMPANY SOU 24-9 and SCU 24A-9 WELL NAME ... SWANSON WIVE, W LOCATION JOB NUMBER $INGL~ SHOT 10-22-75 DATE THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence. Additional copies of your survey report can be made from the original by any blueprint company, [0~ REPORT TANGENTIAL HETHOD OF COHPUTATION o IV~P WELL NO. SCU 2~-9 Oft_ OCTOBER 22~ 1975 s'.~o'r ~'zAG~ETIC DECLINATION 25 EAST . FOR GRFAT L,~.N[) DIRECTIOn]AL DRILLING BY F.~. LINDSEY AND ASSOCIATES RECORD OF SURVEY ALL CALCI.!LA'rIONS PERFORatED 3Y I B M ELECTRONIC COMPUTER TRUE "4E,,qS, Df:':,IF'f VERTICAL DEPTIt A!VGLE DEPTH SUB DP, t FT SEA DIREC DEG, 0.00 -139,00 N 4 E 134,99 -4,00 N 4 E 232.98 93,98 N 38 W 353,97 214,97 N 56 W 56.3,97 404,97 N 55 E 799.96 660,96 N 76 W 1051 0 24 1050.95 011,95 P..t 60 W ~2';"/ 0 10 1296,0fi 1157,95 N 17 W ]5/,~ 0 15 ]5t~7.95 1408,95 .5 5 E ).~or.~ O 22 1799,94 1660.9a 5 10 W 20:'~r~ O 15 ~079~g& ],940,94 S 17 E 23()5 0 15 2364,94 2225,94 N 67 E 26~,q 0 15 2613.94 2474,9a S 79 E 2866 0 15 2865~93 2726,93 5 55 E 31r)6 0 24 3105.93 2966,93 $ 30 E 33~7 0 15 3396,92 3257,92 S 60 ~ 367q 0 15 3677.92 ~538,92 S 40 E 3772 0 15 377i.92 3632,92 N 68 ~ q.O~5 0 ~,.5 4084.89 39~5.89 N 60 E 4295 0 15 4296.89 &155,89 N 20 E 4.577 0 30 t~576,88 4,437.88 N ~ W 4963 0 45 4962',85 4823,85 N 1,1 W 53a9 2 0 5368.60 5229,60 N ~ W TOTAL COORDINATES 0.00 5 0,00 W 1,17 N 0.08 E 2,18 N 0.70 W 3,17 N 2,17 W 3,46 N 1,77 W 4.00 N 3.93 W 4,87 N 5,45 W 5.57 N 5,66 W ~.48 N 5,57 W 2,88 N 5.85 W 1,71 N 5.49 W 2,20 N 4035 W 1,99 N 3,28 W 1,36 N 2.38 W 0,08 S 1,54 W 0,72 $ 0.44 W 1,66 $ 0e33 E 1,50 S 0.71 E 0,54 N 4.26 E 1.40 N 4.57 E 3,85 N 4.40 E 8,81 N 3,44 E 19,17 N 6,21 W CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/1OOFT SECTION DISTANCE 0,00 $ 0 0 0 W 1.17 N 4 0 0 E 2,29 N 17 56 8 W 3.85 N 34 25 36 W 3,88 N 27 ~ 47 W 5,61 N 44 31 41 W 7,31 N 48 11 22 W 7,95 N 45 27 56 W 7,15 N 51 9 58 W 6,52 N 63 46 47 W 5,76 N 72 40 13 W 4.87 N 63 10 37 W 3,.84 N 58 45 32 W 2,74 N 60 15 ~1. W 1,55 S 86 46 47 W 0.85 S 31 55 53 W 1.69 ,5 ll 30 16 E 0.000 .0,370 0,515 0,218 0,476 0.238 0,064 0.122 0.166 0,057 0,066 0,130 0,059 0,041 0.085 0,076 0,031 1,67 $ 25 28 42 E 0.313 4,30 N 82 46 30 E 0.161 4.78 N 72 58 50 E ....... 0,277 5,85 N 48 49 2 E .... 0,103 9,46 N 21 20 17 E 0.068 0,00 -1.17 -2,17 -3,13 -3,~3 -3,93 -4.77 -5,47 -4,38 -2,77 -1,61 -2,1~ -1.93 -1.31 0.11 0,73 1,65 1e49 -0.61 -1,48 -3.93 -8.87 20,16 .N...17 5,? .... 57. w ............. 0,.35.0_ ..... -19.06 RECORD OF SURVEY ALL CALC~L. ATIONS PE,qFOR",IED 3Y I B N~ ELECTRONIC COMPUTER TRUE ',t.~rt~':. DRIFT VERTICAL DEP T!'i A ,~(:, LE DEPTH SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES DOG LEG C L O S'U R E S SEVERITY .. DISTANCE ...........ANGLE D M $ SEC T ! ON DISTANCE 555.5 1- 30 5555.5h 5416,~4 N 33 W 57'75 2 30 5774.33 5635,33 N 22 W 5931 2 15 5930,21 5791,21 N 27 W 616t~ 2 0 6163,07 602~,O7 N 26 W 62~ 2 30 6229.00 60g0,O0 N 8 W 65~o 2 0 6537,82 6398,82 N 7 E 67~5 2 0 6733,70 659~,70 N 5 E 7007 1 45 7005,57 6866,~7 N 12 W 7097 ~ 15 7095,32 6956,32 $ 11 E 71S9 5 15 7186~9~ 70~7,9~ S 10 E '7~lh 5 0 7311,46 7172,46 S 9 E 743? ~,.45 7436,03 7297,0~ S 5 E 7534 5 0 7530,67 7391,67 S 5 E 7629 5 15 7625~27 7486e27 $ 2 E 7755 5 45 7750,6~+ 7611,64 5 1 E 7RBl 6 0 7875.95 77~6,95 S 8 W 794~4. 8 a5 7938.21 7799,21 S 5 W 8037 10 1'5 802q,7~ 7890,73 $ 3 W 816~. 12 45 8150,67 8011,67 S 8 W 8255 19 30 8241,25 8102,25 S 2 E 83a8 17 30 8329,95 8190,95 S 2 E ~472 21 0 82~45,7] 8~0&,71 S 1 W 8601 2&. 30 9563,10 8/+2/+,10 S i W 8665 26 0 ~620,62 8481~62 $ 2 W 8842 ~F'+ ~0 8779,02 8640,02 S ~ W 90~'~7 26 15 8962,88 882~,88 S 5 W 9372 2z~ 30 9258,62 ~119,62 S 10 W ~r~ 24 30 9~6~,18 9225,18 S 2 E 956':, 25 30 9433,67 9294,67 S 2 E 23,28 N 8.88 W 32,14 N 12,46 W 37,59 N 15,24 W 44,90 N 18,80 W 47,75 N 19,20 W 58,46 N 17,89 W &5,2'7 N 17,29 W 73,40 N 19.02 W 66,85 N 17,75 W 58,56 N 16,29 W 47,80 N 1~,58 W ~7,49 N 13,68 W 29,2~ N 12,96 W 20,55 N 12,66 W 7,93 N 12,~3 W 5,10 S 14,27 W 14e65 $ 15,10 W 31,18 S 15,97 W 58,28 $ 19,78 W 89,98 S 18,90 W 111,3~ S 17,99 W 155,76 S 18,70 W 209,25 $ 19,63 W 237,29 S 20.61 W ~15,96 S 27,50 W 406,29 $ ~5,40 W 539,02 S 58,80 W 587,09 S 57,1~ W 620,22 S 55,97 W 2~,92 N_20 .53 11 W ........ 0.912 3~,47 N 21 11 41 W a0,57 N 22 ~ 11W 0.208 ~8,68 N._22 ~3 ~2 W ............... OelOB 51,47 N 21 5~ ~O W 1,30~ 61,13 N 17 1 10 W .. 0,2~9 67,52~N 1~ 50__3~_W ............ 75,82 N 1~ 31 5~ W ..... 0,223 69,17 N 14 52 19 W 6,666 -31,90 -37,31 -~7.39 -5B,12 -64,94 -73*03 -66,51 60,78 N 15.32..~5...W ............... 1,091 ........ -58,25 49,97 N 16 58 11W .... 0,212 39,91N 20 3 11W 0,337 31,98 N 2~ 5~..28 W ........ 0,263 24,1~ N 31 37 ~3 W 0,386 14,75 N 5~,28 14 W 0,404 15,15 S 70 18 26 W ....... 0,757 21.04 $ 45 52 15 W 4e~06 35,03 $ 27 7 ~3 W 1e651 61,54 $~18__~4.56 W .... 2,169 ...... 85,50 S 12 46 28 W 112,77 S 9 8 55 W 156,88..$ 6 50 52 W 210,17 S 5 2I ~2 W 238.18 S 4 57 57 W 3,901 2,151 2,932 2,713. 2,437 ~17,16 $ 4 58 28 W 0,801. 407,83 S 4 58 48 W 0.122 542.21S 6 13 35 W 0,851 589,86 S 5 33 28 W ..... 4,283 622,74 $ 5 9 26 W ~,299 -47,52 -37,23 -29,00 -20,32 -7,70 14,9~ 31.4' 58-63 8~.71 111,64 156.08 209.57 237,63 316.41 406.87 540.00 ~21.14 RECORD OF SURVEY ALL CALCULATIONS PF. RFOR~ED ~Y ! B M ELECTRONIC COMPUTER TP,(IE :~tEA.q, F',r~IFT VERTICAL ~.EPlfl AF.:OI.E DEP'TH SUB DRIFT SEA DIREC PEG. TOTAL COORD INATE5 9921 25 ~0 9755,53 9616,53 10013 ?5 ~5 9838.z~0 9699,~0 10203 f~6 0 ],0009,!7 "9~70,17 10297 26 0 10093.66 995/+.66 10~52 26 30 10232.37 10093.37 10533 2~ 30 10306,08 10167.08 106~6 23 a5 101,18.66 10279,66 107:~5 27 $~5 10490.97 ].0351.97 10856 23 0 10602,35 10463.35 11056 2~ 0 10786.45 106fl7.t~5 685.45 S 53.69 W 714.1~ $ 52.19 W 772.04 S ~7.12 W 811.96 5 45.0~ W 895.13 $ 40.67 W 936.31 $ 39.23 W 1005.38 S 35,61 W 1038.92 $ 33.85 W 1088.3/* $ 30.40 W l120.1fl $ 29.29 W 1167.35 $ 26.81 W 12q5.~9 S 22.72 W BOTTOm:4 HOLE CLOSURE 1245.60 FEET AT S 1 2 43 W ccOsu. F.s DISTANCE ANGLE D M S DOG LEG SEVER I TY DEG/1OOFT 687.55 $ 4 28 4~ W 716.05 $ ~+ 10 ~+7 W 773.~8 S 3 29 34 W 81~.20 S 3 10 28 W 896e06 S 2 36 5 W 937.1/+ $ 2 23 58 W 1006.01 $ 2 1 4~ W 1039e~+8 S 1 51 59 W 1088.77 S 1 ~6 0 W 0.163 0.725 0,732 0,979 0.132 0.~66 0.~31 2,469 0.696 1120.52 S 1 29. 52 W 1.020 1167,66 $ 1 18 57 W 0,701 1265,60 $ 1 2 ~3 W 0.000 SECTION DISTANCE 7~.98 772,78 812o6~ 895.73 9~6°88 1005.86 1039,37 ~088e72 1120,~9 1167e65 12~5.60 '" '", "'""" t'!':t'TP.t, ,.,~' -"" "', .. ~., n'~'l.i:'',. , , .... ,. DATA F'OI-~, E\,'E:RY EVEN 100 FEET OF SUB SEA DEPTH. 'F~', ~I.° VERiI('.:~I. SIlB ,UD-TVD VERTICAL DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES ?'~o 239. 100. 0 0 339 339. 200. 0 0 439 439. 300. 0 0 530 530, 400. 0 0 639 639. 500. 0 0 739 739. 600. 0 0 !~39 839. 700. 0 0 939 939. 800. 0 0 ~ n3g !039, 900, 0 0 ].137 1139. 1000. 0 0 ] 2'30 1239, 1100. 0 0 ].339 1339. 1200, 0 0 1439 ].439, 1300, 0 0 1539 1530, 1400. 0 0 1639 1630, ],500. 0 0 1739 1739, 1600. 0 0 1839 ]gBg. 1700, 0 0 19~9 ]930. 1800. 0 0 2039 2039. 1900~ 0 0 2139 21139, 2000. 0 0 2~39 223Q, 2100. 0 0 23'39 2339, 2200~ 0 0 2~39 2439. 2300, 0 0 2539 2530. 2~00, 0 0 2639 2639. 2500. 0 0 2'739 273~. 2600. 0 0 2R39' 2830. 2700. 0 0 2939 2939. 2800. 0 0 3039 3039. 2900. 0 0 3139 3i3~. 3000, 0 0 3239 3239. 3100, O 0 3339 3339. 3200, 0 0 3~39 3~39. 3300, 0 0 3539 3539. 3~00. 0 0 3&39 3639. 3500. 0 0 2.23 N 0.78 W 3,05 N 1.99 W 3,30 N 1,99 W 3.~5 N 1.78 W 3.66 N 2,57 W 3.87 N 3,~2 W 4.14 N 4.17 W 4.~fl N 4.77 W 4.83 N 5.38 W 5.12 N 5,5~ W 5.41 N 5.61 W 5.39 N ............ 5,65. W 4.96 N 5.61 W ~.52 N 5.57 W ~,90 N 5.67 W 3,27 N 5.78 W ~.72 N 5.80 W 2.30 N 5.67 W 1,88 N 5,55 W 1.81 N 5.26 W 1.98 N ~,86 W 2.15 N .......... ~,~5 W 2.1~ N ~*03 W 2,05 N. 3,60 W 1,93 N 3-19 W .......... 1.68 N 2,8~ W 1.43 N ...... 2.~8 W ..................................... 0.92 N 2,13 W 0.31N 1,78 W Oe15 $ .......... t,42._W 0,~7 S 1,04 W 0,59 $ 0,66 W 0,86 $ 0,~3 W 1.19 $ 0.05 W . . 1.53 $ 0.22 £ ";E~SUPL'f~ DEPTH AND OTttER DATA FOR EVERY £VEN 100 FEET OF SUB SEA DEPTH. _, . T R U E r ;r/~,5~jlt E.r) VERTICAL SUB ~D-TVD VERT ~ CAL OEP I'H DEPTH SEA DIFFERENCE CORRECTION TOTAL. COORDINATES 3V79 ]'739. 3600, 3n3q 3P39, 3700, 3')3q 3939, 3800, 4039 4039. 3900, 4].Dg 4139. 4000, 4 2 ~ 9 4 ~ ' . ... .; 3 ~. 41 ',")0 · 4339 a33a. a200. 4/,~ ';." 9 A439. ,/+300. 45~g' /4' -5 ~c) ·1'," 400 · 4.639 463g,,' 4.500. 4 ? q 9 4 '? 3 ?. ~ 60 0 · 42?9 t+839. 4700. /*939 4939. 4800. 6039 5039~. 4900. 5!39 513~?o 5000. 5239 5239. 5100. 5339 5339~ 5200, 543~ 5439~ 5300. 553C~ 5539, 5400. 56a0 5639. 5500. 5740 5'739, 5600, 5a40 58~9. 5700. 5~40 ~,~3e. 5800. 6040 60~9, 5900. 6!40 61,39. 6000. ,S ,1"] ~, () 62 2' 9 ~, 6100, 634 0 6 Z F 9 .~ 6200, 64. 4 0 64 ,) 9 · 6300 · · G q/~,f~ ¢,SSo, 6400, 664. n a(~?9, 5500, 67~0 677g. 6600, 6a40 6839. 6700, 6940 6930, 6800, 7041 7030, 6900~ 7141 7139, 7000, 1.56 S 1,06 0.41 0,24 N 0.76 N 1,17 N 1.78 N 2.65 N 3,52 N 4.65 N 5.93 N 7,22 N 8,51 N 10,76 N 13.31 N 15,86 N 18,~2 N 20.72 N 22,92 N 26.66 N 0,58 E 1,~7 E 2,61 E 3,74 E 4,34 E ~,49 E 4,55 E 4.49 E 4.43 E 4.25 E 4.00 E 3.75 E. 1.6~ E 0,75 W 3,1~ W 5,51 W 7,22 W 8.6~ W 10.25 W 30,71 .... N 11,88..W 34,40 N ~7,87 N 41,01 44,15 N 48,10 N 51,57 N 55,0~ N 58,50 N 13,61 W 15,37 W 16.90 W 18,44 W 19,16 W 18.74 W 18.31 W 17.89 W 61,98 N 17,58..W 65,43 N 17,33 W 68,42 N 17,96 W 71,41 N ................ 18,60 W 70,96 N . 18e55 W 62.90 N 17,0.5 W I~"FFE;:',t,~OL. ATED TF-'.:UE VFP, T-ICAL.PFPTHS, COORDIi'tATES AiNu CLOSURES FOR GIVEN DEPTHS TRUE ',~EA SUREb VFPT ICAL TO'TAL COORD I NATES DISTANCE ANGI.,E ....... D ~ s su~ SEA ! l.,-.& POI-T !,~- 10 '1" DP 10'?0~ 10568.0~ 1052~69 $ 72,62 E 10822 1059~.35 1060~91 $ 78,90 E 10996 !0701,47 lOgO~& $ 104,~8 E 1.09~0 107~2.82 1101~70 $ llA,~5 ~ 1011,~5 5 2 7.16 E 10275,78 1056.19 5 3.56 33 E 10429,0~ 1063,85 1095,3~ 5 I107,62 $ ~ ~S ~4 E 1060~,82 ~. 1E A 5 ~r)FP D~'PTH AND OTktFR DATA FOR EVERY EVEN 100 FEET OF SUB SEA~ DEPTH. ~'qPTH ~r:' F; 1'~,~ SEA D [ F'FERFNC~'£ CORRECTION TOTAL COORDINATES 77.4.2 7377. 7200, 3 1 'z4A2 7439, 7300, B 0 't5~2 7539. 7400, 3 0 7643 76~9, 7500e 4 7743 7739~ 7600, 4 0 78~4 7839, 7700, 5 79~5 7939, 7800, 6 1 ~,047 ~039. 7900, 8 2 S~.4Q 8139, 8000, 10 2 8253 823g, 8100.. 14 8358 R339, 8200, 19 5 f],465 8439. 8300, 26 7 8575 8539, B400, 36 10 8686 8639, 8500, 47 1t 8797 8739, 8600, 58 1 1 8909 8839, 8700, 70 12 9020 8939, 8800e 81 11 9131 9039. 8900. 92 9241 9139 · 9000. 102 10 9350 9239. 9100, 111 9 0460 9939. 9200, 121 10 9571 9439, 9300, 132 9681 9539. 9400, 142 10 9792 9639, 9500, 153 9903 9739, 9600. 16k 1,001~ 9830, 9700, 175 11 10125 9939. 9800. 186 11 10236 10039, 9900~ 197 10348 lO13q, 10000, 209 12 30459 10239. 10100, 220 10569 10339. 10200, 2~0 10 ][~6'78 10439, 10~00. 239 9 1D787 10539. 10400, ~48 9 54.06 N 15.57 W 45.52 N i4,38 W 37.23 N ._. 13.66 W 28,47 N 12,93 W 19.17 N 12,63 W 9elO N .... 12.46 W 1.26 $ 13.73 W 14.79 $ 15.11 W 33.25 S 16.26 W 55e66 S 19.41 W 82,76 $ 18,92 W 11~.80 $ ..... 17,99 W 153.18 $ 18.66 W 198.27 S 19.~4 W 296.08 $ 25.76 W ~45,~ $ 30.07 W 39~.55 $ 34e37 W 5~0~21.$ 57,25 W 575,6Z $ 57,52 W 622e7~ S 55e88 W 669e$6 $ 5~e2~ W 716.67 S 51,96 W 76~.18 $ ~7,81W 812.25.$ 45,01 W 860.95 $ ~2,46 W 909,67 $ 40,16 W 958.89 $ 1008,39 S 1053.37 $ 1097.28 $ 1140.50 S 38,0.5 W ...... 35,4.5 W ..... 32,84 W 30,09 W ........... 28.22 W IrITr'~POLATED VALUES FOP, EVEN 1000 FEET OF HEASURED DEPTH, T r~ IJ E ~!F ~ :'.'~U R E P V E 2 T ! CAL SLJB DFPTH DFPT!,4 SEA TOTAL COORDINATES 1000 999, 860o 2000 t999, 1860, 3000 2999, 2.860, a. O00 3999, 3860, 5000 ~g99. ,"+860, 6000 5999, 5860, 70('}0 6998. 6859, 8000 7993, 785/+, 9000 8920, 8781. lOOOO 9826. 9687, 4.70 N 2.0~ N 0,55 N 0,01 ,,5 9,76 N 39,76 N 73.19 N 24.60 385,58 S 806,32 S 5,1/~ W 5.60 W 1,91 W 3,30 E 2,56 E 16.29 W 18,98 W 15.62 W 33,59 W /+5,32 W ~'~C)~! REPORT TANC~F. NTIAL t-!ETHOD OF COMPUTATION !~IVUP WELL NO. SCU 2AA-9 OiL OCTOBER 22,1975 FOR GRFAT I. AND DIRFCTInNAL DR LLING DY F,M, LIND~EY AND ASSOCIATE~ !?FCORf) OF SL,'RVF. Y ^,LL ,C.^LCt~L.,~',Tlr,~H,~ PE~FnF,'t~FD BY ! B ~ ELECTI~ONI¢ ¢Ot~lPUTER SEA DIREC TOTAL COORDINATES SC~.~ 2A-9 REDRILL KOP AT 9921 FT, ~ASU;<ED DEPTH iOnr.,."'25 30 982B,,E, 3 96t]9.63 $ 3 E ~C~097 25 0 99],/+.73 9775,73 ~ ~ E 10202 22 0 10012,09 9~73.09 $ 7 F' 1.0~22 i0 15 101.25.38 9986.3~ S 22 E 10a77 21 C) 10265,70 10126,70 $ 37 E 1099F~ 20 90 1,03~3,'72 102~.72 $ 38 E 1.06~a 1,9 t, 5 1O~6a,.t~3 10329.&~ $ 38 E 107~q 20 0 ]056~.3t~ lOt, 2A~ga $ ~.0 E 10~() 20 n lC~620,66 10a~1.66 $ A1 E 1103o 20 0 10789,80 10650,80 S A1 E fl06,86 $ a5.29 867,00 5 AA.59 886,0~ $ 39.80 922,72 5 2~,98 9~2,01 $ 1§,~7 967.20 S ~.~0 1001.97 ~ 30.57 1025,93 $ a9.29 1052,40 $ 71,50 106a.la $ 85.18 1114.61 $ 1~5,57 HOLD CLOSLH~F 1121,66 FE~'T AT $ 6 2.5 ;+1 E CLOSURES DISTANCE ANGLE D M DOG LEG SEVERITY DEG/IOOFT 773,47 S ~ 29 D3 w O.ono 808,,1:~ 868.17 886.94 '923,06 942 · 14 967.20 I002,~ 1027.12 105~.82 1071.53 1.06~ _1.0~I ~*681 2,711 0*486 0.717 0.561 1121,66.$ ...... 6 25.41 E 0,000 SECTIg DISTANCE 761,91 796,72 836,68 876.02 961.50 999.09 I02~.00 1053'1 1070. o 11~1,66 DEPTH ANO OT't.!i.~'R D'ATA FC)R EVERY EVEN 1.00 FEET OF SUB ,SEA DEPTH. TRUE VE~," T :[ C^ L StIR t"~D- T VD VERTICAL D,:": P T Ft .SEA D'[FFEREN 'E COt~RECT ION TOTAL COORDXNATES !.0013 9839, 9700, 174 174 10123 9939. 9800. 18~ 10 t023], 10039, 9900, ]92 8 ~0~37 10139, 10000, 19~ 6 ]Oa~3 10239. 10100. 204 6 ~1590 10339, 10200~ 211 7 ~!6~7' ~Oa3~. 10300, 2]8 7 ]n763 1.053a, 10~00. 22~ 6 811,69 856,7~ 894.75 927.24 959,0~ 988e79 10~7,6~ ~04~.61 ~5.21 W 43.39 W 36.28 W 22.77 W 2.76 W 20.27 E 42.79 E 65~80 E I~'~l"~'-'"-'~'[:r't~ -~....ATED VAL'~JFS F'('}~'", EgEN 1'000 FEET OF' ~,4EASURED DEPTH, '."E' ,'; :.G t..! r~. ED Vc:[ R l' I [ AL SUB !'~- !:; !-~ TH DE P T ~t SEA TOTAL COORDINATES 10000 806,00 S .... HORIZONTAL 'VIEW SCALE i"=500" .... STANDARD OIL COMPANY OF CALIFORNIA ' WELL No. SCU 24A-9 - .............................................................. TANG ENT!AL -M.E T HOD . .. · . . 7200T '7600 8°00 ,r.......---CLOSURE S 06°26'E 1122' 92oo-- ~......--CEOSURE SOI°03'W 1246' 9600 - SCU 24- 9 ~ ~o, ooo- SCU 24A-9 Io,4oo TVD: 10,790' TMD: I 1~0;50' . TVD = 10,786' TMD= t 1,056' IALL DEPTHS SHOWN ARE TVD. - 800 ....... VERTICAL SECTION -16oo SCALE I"= I000' STANDARD OIL COMPANY OF CALIFORNIA WEL'L No. SCU 24A-9 ...... -2ooo .......................................................... TANGENTIAL'-METHOD--'~ ....... 3200 . 48oo 5200 ALL DEPTHS SHOWN. ARE TVD. 5600 6400 72OO 76O0 ~000 GR AT £A D DIRECT O A£ DI I££] G REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDAP~D OIL COM]PANY COMPANY ,. SCU 24-9 SWANSON RIVER FIELD AL875-DTB JOB NUMBER LOCATION $INGDE SHOT 9.,P3-75 TYPE SURVEY DATE THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence. Additional copies of your survey report can be made from the original by any blueprint company. ...... F"E'~-6~RD OF SURVEY ........................................................ ALL CALCULATIONS PERFORN~E-D B.Y I B ~,~ ELECTRONIC CO;,iPUTER TRUE b q'i-~-~ -~) ~ ~-~] ~ Y~-F. SUB -- '-~-P~-~'~'- ..... ~. ..... ~'6TAL COORDINATES C L 0 S U R E S DIREC DI STANCE ANGLE DOG LEG SEVERITY DEG/IOOFT' D.J.STA~CE D ',~ DEG, D N S ......_~ o ~. o.¢o -1~9.oo ......$i ...... ~-"k ................. e.oo s o.oo w o.oo s o o 135 O 30 134,99 -~,00 ~,l a E 1,17 Iq '0,08 E 1,17 N ~ 0 ?~? 0 45 232,9~ 93,98 N ~8 W 2,lB N 0,70 W 2,29 N 17 56 ..... ~ "5"5~ .... ~-~'i~7 2~;"5~ .... ~-'~--9~ ............... ~'.'~'~ ..... ~i ................ ~".~Y--W ................. 0 W C, 000 0 E 0,370 8 W 0,515 36 W 0,218 5z, a C a 5a3,97 aOz[,97 N 55 E . 3,a6 N 1,77 W 3,8B N 27 4 ~7 ',',' 0,a75 ............. ' .... ~C ..................................................................................................................................................................... L ...... !95.!_ Q._.2a__l_QS.P.,95 ...... 9.1. S.,2~ .... ~_60 W 4,..~7__N .......... .~.,~5 W __7,.3.1 .... ~_~h.._}_1.¢.2 .... w. Imm7 O lo 1296,95 1157,95 N 17 W 5,57 N 5,66 w 7,95 N ~5 27 56 W 0,122 .... l~.~ o z~ ..... tsaT,9~ .... lZf~s,.q~ ......... S ...... 5 ..... E ............ 5,~.s ..... N ............... ~,.s7 .... W ................. Z,t.5 ..... N 51 .... 9 ..... 5. s w ~c,lso ....... 18.0: ..... ,=~2 !_Z~__~,o~ 1660,9a S 10 w 2,88 N 5,85 W 6,52 N 63 46 ~7 W 0,057 .. 23e5 C [5 ...... 2~6a,ga 2225,9¢ ..... ~_67_._E ............... 2,.2.0 .... ~ ........~,35 ..... W .............. ~,.87 N_....O3_ ..... lO._~7_.y ....... 0,~0 ._. .................. o ~ ..... 9___~__ 3,28__W __;.,.8~ N' 58._~5_ 32 W 2~55.__ 0_!5._ _2865_.,_93__ .2_~26,93 ..... S__55..E ............. Z,36_.~ ........ 2,3B__W 2,74__.~.__60 .... iS.__~l W __O,O~l ~ _. 31C6 O 2a 3105,93 2966,93 S 30 E 0,08 S 1,54 W 1,55 S 86.._46 .... ~7...W ..... 0,08.~ .... ............................................ ~07 -~'-'~: ....... gme'~'_'oo ..... ~P:Tea2 ..... -q AO E 0,72 S 0,44 W 0,85 S 31 55 53 W 0,076 35v= S ].5 3677,92 3538,92 S aO E 1,66 S 0,33 E 1,69_5 .... 11_.30. 16 ....E 0,031 ................................................................. 3F~2 0 15 3~I,92 3532,~2 ..... ~q..68 E .......... !,50 S 0,~_1 E .............. 1,67 S .... 25 28 ....~2..E ...... 0,313 ........................ ~.~R5 ..... C. .... ~. ~.~?.~9_.. ~.9.~5~.~9. ....... ~...60...E ................ ~..,5~+ ~-~ a,26 E a,30 N 82 46 ~0 ~ _O.~161 ~29~ ~ 15 a2oa,~a a~5,89 N 20 E Z,aO ~' a,5~ m ~,78 N 72 5n 50 E 0,277 ~ ~ ~ ,. ~ ., , - . -- . .................................. ~ ......................... -3,63 -6.17 -.~, 52 I -1,62 -3,08 0,66__ 1,6~ ..~ 1,57 a577 4?53 W E 0,068 _. 5369 _.W W . _ 2 _0 .... 5_35~,6'."; ...... 57. g9_,5.0. __ N_>3 8,81 N 3,4a E 9,a6 N 21 20 17 .......... 1.?,__17.. .... bt .................. ~.21...~' .......... '. ..... 20...I~_.N .... 1.7 .... 57 57 -S,37 -19.75 .__ bC'OT~. /,_,~,,' ~.- .................................. ... . ,-.: :,:.~. ..... DE~TH SEA DIREC ......... _D.. ~. S~T._A__;:I_C E DEG, .............. D . .~_ .... ~! ............................................................................ DOG LEG DEG/iOOFT DISTANCE '-' =77= 2 BO ,~77/+,~3 5~;°'~,B.~ N 22 W . 32,14 N 12,46 W : 34,47 N 21 11 41 W ,.. ,,..' . ................. -[ ,.. ............. ............................................................................. ...... 5C~1~.'-.2___!5 57.!_~.,_21 5791,21 N 27. W .~_7,59 N !.5_?_2...z+.._J~__ __40,57 N 22 4 11 ._ 6~6a.. 2 .... 0 .... 51.63o0.? ...... ~.02_4,..07_ .... ~': 26_!,/ ...... _4_~,90__N.' ........ ~.,.80__~__._. ...... ~.~:6~.__N-22_~.~_._S_2 w __ 6539__2. _0 6~.~..7_,.~2_ 6~8_,8_2_ ..... N_._7__E ......... ~_.8.,.~6_.2.1 ...... 1.~_,8..~__~ .... 51,13..2N_17_ . ..E7~5 .2 .... 0 ..... 6.7~,70 ...... 6594,70 ..... !~.I .... 5 E ............. 65,27..h! -_._1'7,29.__W ........... 67...,52_N 14._.50 ..34_W .... ._ _7007_ _!...~5 _7_0C5.,.5~ ..... _6e66.,.5_.7.___?~ .... 12_.~'. ......... _7__~,z_+_O ..... .N. ............ ~9,.02 W '/5,82__N.1~ ..... ~l__SZ+ W __ .'7 e 97 ...... ~. __1_5__7.~.? 5 ..~ 2_ ..~_~.~. 6.., ~. 2. s__~_I.._E ........ 6.6_._ 85__.LX ...... 1.Z.,._T_5_ .Y. .... .6 ~_,.1...Z.._[q 71 9 5 15 '71~6,9~ 70~7,9z~ S 10 E 58,55_ ~,l 16,2°. 60-.7..8..N._15 ..... 32. ~5 W - 7.~!.~,--~ _._0 .... _7_..~.11_,..z, 6 _7__.172 , .4 5. ...... S ........ 9 .E ............... 47,S.0 ~! ............... 1",58.._V:! ........... (+..9,<27 .... N__16_58 11 .... W.. __ .... ... _ ..... 9 ......... ,_0_ '7" '~ c ._ l, z, .5_ .Tf'.~ _5 ,_0_~ .... 7_29_7 ,.0 ~.___S_ ...... ~. E_ ~.Z..,7+_~__b!. ~ ..... 1 ~.., 68 .... !;'.! 39.,_ ]. 7~'~4 5 '~ 7r"~O 67 7'~Q1,67 S 5. E 29,2a .~[ ........... 12,96 W 31,~8 N 23 .... 5_4 28 W .., .,. ...... ../.,... II ......... ... , ........................................... ' ............. ...... "627 5 15 7525,27 ......7.z,_86_.,27_ ...... S._2 E ...... 20,55._N_ ............. 12,66._W .... ]_.2_4.:.1.4 .... N 31.._ 3.%. ...4 3 W -"~75:. ~ z, 5_ 7790,6A_._?__61i,64 S 1 E 7.e'~ N 12,a~ W _.!....a..,.25 N 57 28. lq. W ............. -, ............................................ ~'..,_. ,,. ........ : .~, 75 ~1___: Q 7975,9_5 ...... :.7B6,95 .... S _.8.__w ............ 5.,10 .... S ........... 1~,27.._W ..........1.5.,1.5__S.~.Q._.1.8.._26 ..... .............................. ~ .............. 21.,0~ S 45 ..... 52 ..... l~..~i ~ ~ a5 7g~,21 77~,2.1 S ........ 5.W .........14,65 ....S ............ i5.,10 t' ............ ~7._10_ 15___80.29,73.. _7.B9..0.,.7~ .... S ..... ~ W .__~],l.~ .... $ .......... 1.~,~_.~: ......... 35.,0.~ _$ .... 27 ..... 7 ..... ~.3 ..... ~ 0,487 0,208 9.,_2 ~.~__ ._0 0,22 ~ -39,0_5__ -49,60 -56,80 -7.5,~___ .... 1,09.1 ....... -6_0'01 .... _0,212 __-~9,.I~__ .O_,~ZT. -~.8,..2~__ ..... 0,26~_ -~Oe~l .... ......... 0e386 ........ ' .21,~4___ .... 0,~0' .... 4.,40~__ 12, 1,615] 2~e19__ GO,7~___ ~1 12 ~,5 .... 9.1D0,67 ~J011,.67__ S _.8 ~, ._5~ 2B S ......... 19_,.78 ' 1 =Z+ .... 5.18..94 .5.6._.?L ....... 2,i69 : 55 1.5_ 30. ...... 82a!,25 .... _6_1.0_2,25 .... .S 2.E ............ 8-~,35_._5 ........... 18,~O._W ............. 85,50 ....$ 12_.46 ....28 W _3,90.1 ..... z, ~ _: 7__3.0_ ...... ~ ~ 2.?, 9 ~ ...... ~ .170.,_~..~_ ...... s _2...E ......... :._1.1., 3 ~__.S .......... 1..7.., .~.3 .._ W ......... .... ~2 21 0 ~a5,71 ~306_.~i ..... ~ .... ~ W .... 155,..76_.S ........... le.,~O_~ ................. 1_5.6.,88 S ...... 6 .... 50 .... 5_2 W__ 2,~32 __ 152,57 _. '-- ~6~I~' 2a 30 8~3,1~~ ~ ...... 8424.,.~0 ....... S ......... 1 >:'. .... 20g,25._5 ......... i9,63_W 210,!_7. 5 ..... 5 21 42 W 2,.213 205,~,. . ~ . ~ ~ I ............................. ~2 25 30 ~77c,02 ..... ~640,.~2 .... S ........... ~ _?~ ........~15,~6 ..S .......... 27_,50 W 317,16 S ...... ~ _~8_28 W 0,8C1 ............. -'-t~-'26 !5 ..... $962,8~ ...... ~.a2~.,.e~ ..... S ......... :..W .......405,2~ s ......... ~,~0 ~ ........ 40_7,83._s. ~ ~a..~e 7__ ~j,~22 ............... ~B72 .... 2a .... ~.0___?.[.~.~,_62 ....~.I~.9.,.6~ ..... S ..... 1.O...~i .......... 53~..,.02 .... ~ ....... ~_,~0__ W 5.62,21 S 6 13 35 W 0,851 ._ ~::...2~_.:~.._~3_5.F..,1.8__~225.,18._ _s.__2 .... E ............ ~.8_.:,_Og .... s ........... 5y.,12_.~ .........~89,.B6 ....s .... 9_._33_28...9~ ...... q,283 _.~7..7,00 .... '- g:55 25 ~0 9~3,67 9294,67 S 2 E 620,22 S ~5,97 W 622,74 S _~ ..... ~__2Z~ W ..... 1,299 .... - .......~ ................. , ................... A L_L ..... C.A_LC.U_L..A T3 0 ~N_S_ P_.E ~ F.Q.~ ~..: E D _.B. Y_ _ ]._.~_%__E _L_E_c'r3_Qj,,L~.C__CO_;~p UT._E R__ T~UE VERTICAL SUB D~IFT TOTAL COORDINATES C L 0 S ..... ~F ~Z.~ ........... SEA. DIREC ............ DISTANCE DEG, 'D DOG LEG E S SEVERITY ANGLE DEG/~OOFT "'c-~?!R 25 15 ~572.06 9433,06 S 2 E 685.A5 S 53.69 W 687.55 S 4 28 4a W 0,163 SECTION DISTANCE 10'2.9 !O2O 10/.7 1067~ 107~ 0,729 2 26 30 9828.64 9689,64 S 3 E 806.B7 S z, 5,29 ~.'! 808,14+ S' 3 12 48 W 1,053 7 25 0 991~,7a 9775,74 S 1 ~ 8g7,01 5 44,59 W 848,18 S ~ 0 50 W 1,041 2.~g .... 1~ ~0_125..3~ ......~g. 9.~..3.9 ........ S_22 .... E ......... 922,~3 S .......... 2~,.98 ~ ....... 92.3.0F._S 1_33 .... 3 .... '<{_. ~,9~6 ~ 20 15 10183,55 !00~,56 S 26 E 9~2,02 c 15,~7 W 9~2,15 S 0 56 50 W 2,711 20 30 10~83.73 10244.73 S 38 E 1001,9~ S 30.56 E 1002.44 S 1 4~ 50 E 0,485 703e81 .... ~6., ~9__. 876.32 ' 93~.35 99.9.10 lo ~5 ~0468e44 ln32~.44 S ~8 E 1029,94 S 49,2o E 1027.12 S 2 45 2 E 0.833 i025,C1 ~. O .... !P.~_.6~ 10424,35 S aO E 1052,a0 S 71,49 E 1054,83 S 3 53 11 E 0.717 1053.79 2C 3 10620,67 1Oa~l,6~ ..... S..A.! E ...1.0~8.,_15 2'.' n 107~9.81 !3650.~1 S al F 111~,61 S__ .125,5.~_.E..: ...... !121,66.S .... 6. 25_.~.0.__E O,3OO 1121,6~ ........ _.. · ......... ,.,--T-E w T.,. LI E. _.V FR.T_~CA L.. - D EF- T.H.S ~ ................................ T~U~- C.2.$-" ........... :_:~.EA__S_L!:_?_52 ...... VS.~_T_I_C4.L._ TOTAL__.__C.._O_O_5?,_J_i[]_A_T[S C L 0 S U R E "_,: ~.~.' --' DEPTH DJ". P TH D I S'TANCE ANGLE .................................................. -. .. SU~ SEA _~-a~? __lq_7_gz, 105.63_,_04 1D_5..%:6_9__5 7 2.o ._6.1_[__1.2 5. .6_. , !'.? S _..]_5.6_~ Z_E__l_O..a.,_2_9.,_O_~ ~'-R _.~c.O ..... I_0 s 2. 2_ ........ 1_059.~:,.36 .......... l 0,(~_0._,_92__s_ ......... 2.8,_9..0 E 106 ~..,..8.5 ..... S__ .z+__.l 5__l.l_E_.!O ~ 5 ~_,_36 __ __ . .~"~. ................................. · ........ ~. . _ _ ~ ...... c LT 10936 10701,a8 1090_ .?, 5__ S.._ lOa,a8 = 1095 ,.~_a_ .... S .... 5_2.8_.2.4_ .... 10.5_62, aS ~ _?_-. lO.._.T_O-o 1_3_9_.R0 !.Q.242_,_8.3__ 1101,_l!_5 1_1.__4.,_~5_~____ 1!_0..l_,.6.2___5 ..,. ........~,N AI, D 9TH; ...... ATA FOR EVERY EVEI'i _I~D .... FE=.T_ OF SU.B_S_E.A.._D.E.~_T.~H_, ' ~E f, SU--.: .=.D ....... VE'.?_T I C/~ L SUg !',~D-TVD V E ?.T_I_.C _A L ................. D. EP.Z~ .............. DEP.T~ _._SEA_.DIFFEP. ENCE .......... CORR.E_C.T.[ON .... _T_QTA.L'. .... CO0_~D_I_NA.TE.$ _ 2 ~ 9 ............. 239: ....... 1.00_, ........... 0 ....................................................... 0 2.23 N ......... 0 .... ~-~ ~?~, 200, 0 0 ~,0'~ ~ I,~9 W -' ~0 N 1,99 W ~9 ................. ~ ~ 9. ..... 300 ~ ........... o.. o ~.. ~ ........................ 5~ ~ ~eo, ...c .......................... 0 ...................................................... ...... - ................... -- ' ........ ~,~5 N Z,?8 W ~39 779, 600, 0 0 3,87 N 3,~2 W . . . .................B3c ~m~,~.. ................. 700, .0 .............................. ,. q ~,1~ N .... ~,17 W 939 939, 800, 0 0 ~,~8 N z~,77 W ............................................ . ............... 113g !1~,9, lO00, O 0 ~,12 N ~,b3 W ......................................................................................................................... .......... 1R3g_ 1239. ..... !lOg, ............ ~ ......................... ~._ 5, ~.L.~ ................ 5.,..61 W 1339 !339, _. 1200, ............ 0 ....................0 ................................. 5... , .3 9.... ~] ................. 5,65_..W . 1439 la3g, 1300, 0 0 4,96 N 5~61 W 1639 163'~, 1~00, 0 0 3,90 N 5,67 W 193~-- ~1939, 1800, 0 0 --2,30 N 5,67 W ...... . 2039 20~o, 1900, 0 0 1,88 N 5,55 W ....... 9 2239, 2100. 0 0 1,98 N 4,86 W ~39 273m, 2600. 0 0 1~68 N 2,84 W 93° 2939, 2800, O 0 0,92 N 2,13 W 23~ 333g* 2900, O C 0,3! N 1,78 W ............................................................................ ....... ~ ....... 313.g_. ..... 3090, ......... ~ ................. C 0,1. 5 L,'2 W ~ m23g,.. 3100, 0 ~,~ 0,37 S 1,0A W ..................................................................................................... ...... ~ _3.639, 3500, 0 0 ........................................................... - . ......................................................... ~,~3 S 0,22 E . 213 223 .. 2 2 2 2 2 3 313 Z2~, 3t, 3 363 .. x_LE A $ U R E D.._ D.E .q T_H_ AjN D_. 0 T..H. E R. _D A_TA_F__O F_, _S V E ~y_ E _V.E ;.~ .... I_0. O_EE E_T_ _O.F_ S U.B. __S EA--D.F.P_IB.., _ TPUF. -. '."EASUO=D VFoTICAL cUB N'D-TVD VERTICAL ....... · k~-. _. ' ' _~,, .... D.--'. = TH .............. DE R.7...N_. .... 5.EA _D I _FF E RF..NC_E_ ....... _c__o_~3__E~_T__I ON __. 4~3 3839, 3700, 0 0 1,05 S 1,47 E ~ 393g, 3800. 0 0 0.~1 S 2,61 E 9 4039, 2900, 0 0 0,2~ N 3,7a E 9 a2~g. 4100, 0 0 1.17 tq 4,49 E ............................................................................ O a3~9, a200, 0 0 1.78 N a.55 E ....................................................... ........................................ 9 ............ ~539. ...... ~oq. ............ o ..................... 3 ........................... 3..._5A.~_ 4,.93 E OQ., ...... O 0 5._?3 N __4.00 E go. 0 0 7,22 N 3,75 E 00. 0 0 8,51 N 3.50 E ......... 5130,_. 5000, 0 0 13,31 N 0,75 W 5239, 5100, 0 0 15,86 N 3,13 W 5339. 5200. 0 0 18.42 N 5,51 W 5a39, 5300, 0 0 20,72 N 7.22 W 5539, 5~00, 0 0 22.92 N 8,64 W 639, 5500, 1 1 26,66 N 10.25 W '~39, 5600, i 0 30,71 N 11,88 W ~99. 5700. 1 0 34.n0 N 13.6i W 93.9.,__5.800, .......... ~ ............................ 0 ~7,87 N 15,37 W 539o 5900, ............ 1 .......................... C ............................ ~1,_01_._~ .......... IS,.?Q. W 139, .._6000_, ............. 1 ...................... 0 ............................... ~,15 .... ~ ............ 18,~4 W 2 ~ ~. ...... 6_!..q~. ........... ! ................................... O ................. ~.~.._..!.¢_~ ............. ~ ?.,_~.6 w 3~9. 6200. 1 0 51.57 N 18,74 W 6~39. 6300. 1 0 55,03 N 18,31 W ~53~.. ..... 6400. 1 O - 5_8.50 N !Z.8.? w 5639, ..... 6500, .................. 1 .........................0 ................................... 61.98._A1 ................ 1.7,58 W 6739. ...... 660.Q:. ............ 1 ....................... O .................................. 65.43 N 17,33 W ........... _aT~ 4739, a6 aosg 4899, a7 z+939 4939. 48 523~ 5339 5a39 5740 5 58~0 5 ............ 5~aO 5 60a~ 6 61aO 6 62a0 6 69a9 6 65~3 67Z, 0 ~z,O ............... ,Sg~, ....... 6SOO.. ........... 1 ............................. 0 ................................. 7I...EI_.?_! ................ 7 r,,,.a l ............ 703.°: 69Q.0. ............... .2 ................................ 1 ............................... 70._95 .....~J ............. lS · 55 71Z*l 7139, 7000, 2 0 62,90 N 17.05 '',iE'ASu~E.~ O.r,.PTH AN9 OTHE~ DATA FCR EVERY EVE'N 100 FEET OF ,SUE SEA .DEPTH. 73a2 733g, 7200, 3 1 v&a2 7a~9, 7300, 3 0 ~5~2 75~9. .... 7400~ .......... ~.~ ........................ 0 ...... ~6a3 7fi39, 7500, a 1 .............................. ............ ~J~, 7739. 7800. 4 o . 7~4~ 7939, 7700, 5 45,52 N 14,38 W 37.23 N 13.56 W 28.~7 N 12.~3 W 19.17 N 12,63 W 9,10 N 12.a6 W 1,26 S 13,73 W 794 814 ~ a5 ........... 913 ............ ...... !OOl _ _ !055 7939. 7800. 5 __1 1~..,.3..~._~ __ 1~.11 .......... W 8039, 7900, 8 2 33,25 S 15,26 W 8!39, 8000, 10 2 55,65 S 19,41 W 8239. 8100. 1~ 4 82,75 S 18,92 W 8339. ~200, 1° 5 lla,80 S 17,99 W 8439, 8300, 26 7 153,18 S 18,66 W 85 ~-9. ~4 ~ 0", -~ ..................................... iO .... 1~8~27 -~ ........... 19,44 W 5 8639, 8500, &7 11 246.~1 S gl,al W o .............. 8 ~'3'~; ...... ~ 7 ~5" ............ i'0 ............................ 1'2 3 ~ ~ .-4 ~--~ ....... ~ 6; ~ 8939, ~800. 81 11 39~,55 S 34.37 W 1 9030, 8900, 92 11 440,a5 S al,42 W .............................. D 9239. 9100, tll 9 530,21 $ 57,25 W O 9339, 9200, 121 10 575.62 S 57,52 ................... ! ............. o~39. ...... 9.30Q. ....... 1.3.2 ............................. 11 62,~.,..!~__~ ...... 55.,.8~ W 1 c53e. 9&O0. 142 10 669.86 S 54,2~ W 2 :15~,_.95o¢, ......153 ................................ ~1 ............................ 71¢,57 .... s ............... 51.,~5 3 o739. 9500. 16a 11 7¢.~,_.!8 S 47,.8.~ W .................. o co.3~. ~800. 184 10 ~56,73 S 43,40 t.~ ~ - . . . ........................... ~ .................. . .... ......................... 7 ............. 10]~9._.10000. ...... 199 ............................. l .......................... ~2!.2~_s ............... 22.~8 3 10239. 10100. ..... 2ca ......................... 6 ............................. ~59.01_._5 ................ 2.77 .................. ~___ 10.~.3.~..__10300. .......... 218 ................................ 2 ...... lO17_.6.! S__ 42_,7..8_E 3 1..o.fi~9.__l.O.~.O.Q. ...... 22¢ ............................. 6 ....... 10.¢f5_.._6_I_.$ 65,79 E !076 .... I .... ~- .;OLATED VALUE.$._FOR E_V_.E~.!__IO00 FEET OF F~EASUPE:D._D.EP_T_fj. ....... T.~U-~ ','z,a SUq E.D. ......... __V F ~, T I CAL SUB -. ~ S P. TH S E A ....... _TO.TA L C QO_R..C. I__N_A__T_g.S __ 10 .r)..O ................ ~.99, ......... 8 60, ._ 2000 ............ 1999, ....... 1~ _3.200 ........... 2O~g, ........28 ...... ~000 ._3q99, .... 38 ~000 .............. ~9, .... ~8 6020 ........ 59~9, 58 BOOO .................. 7995. .......78 60, ........... 2., 0.~, ._.:'~ ............... 5, 60._.W 60. .............. 0.,..~..5_..~! .......... :t · 91 .... ~.,_: ...... 60. .................. _0 ,.0 I_.S __:~, 30_E__ 60. .................... 9,.70 .... ~! ........... 2_. 5~_..E ................ ~0. ......... ~9: 76._.N ..........1..5,29 W ................................. .~ .~, .............. .'7_3.1.9._.~I ....... ],..~., 9 t~ w 5~+, 24.60 S 15,62 W 9000 ................. 8920, ........... 8781, ...... ~85,58_.5 ........ 3:e59 ....W.__ !e q826, 9687, ................................ ?'00_ .......................................... 806,01 S 4.~,34 W . . · i ! ' ~ SCALE ]": 500' - ._.- : - , .... ~ ............. ,~., - , . ! ;: ...... -' ~ "' t ' i ..... STANDARD OIL COMPANY. OF CALIFORNIA - :- -; ' '""' ._~ ............... '._.~..~ .......... ', ...............................J. ........... ].-..:..__.~i .... :]_:'.~ .... WELL No. SCU 24-9 ......................... ' ! ' ' ' t TANGENTIAL METHOD ' "' ...... ! ........ ~ ....... l ............: : -: ................. i .... ' .......... ~ .......... ~ . ~ ....... !__ i ......... -- i L . : · ~ , : ~ · , ....... -..--,. ......................... _ ................ ; ......... . ................................................. , iTVD = 10,790 ' s ' , .......... ' '!TMD 11, O50' .. , - s .... : CLOSURE: .............. S 06°'26~ E 1122' -- .... · .: ALL DEPTHS SHOWN 't ...... ARE TVD --- _ t I 6400- 7600 - c , ! .VERTICAL.~ SE TION '-!. SCALE i"= ~ooo' , ..... .. ) i 'i.i'. I STANDARD OIL COMPANY OF CALIFORNIA ....... .................. ' ' ' i ' WELL No. SCU 24-9 . . . i _ "~ -..-'---'TA'NGENTIAL METHOD . .. ! .......... : ' t .... t . . : ...... ~ ...... i .... · . ..... ! ...... : : ...... , .... : .... i, .......... ', . i ........... , TVD: 10,790' TMD: 11,030' TRANSMITTAL ANt) .(NOWLEDGE~NT OF RECEIPT OF MA~ 'AL - (ALASKA) TO: DEPT.: PLACE: Mr. T. R. Marshall 8tare of Alaska Di'vlslon of OI! & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline TIlE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE Ib~IEDIATELY. COMPANY WELL ,...~0__~ ,g.t.~ ~q .4-. % h ~ HISTORY LOG 2" 5" _4_ I-L IOO 200 RECEIVED BY f"tEMARI(S' ON OTHER SID[~ THIS BY u , ,x%n/, ,re '("~'?x,"~ ^ ....... q..., x ORIGINAL COMPLETION REPORT - NEW ~![LL STANDAI~) OiL COMPANY' OF CALIFORNIA, WESTERN OPERATIONS. INC., OPERATIONS AREA: Swanson River Field LAND. OFFICE: Anchorage Kenai peninsula Alaska PROPERTY: Soldotna Creek Unit WELL NO: 24A-9 LEASE NO: A-028997 AP1 NO: 50-133-20273 LOCATION AT SURFACE: 2,411' North and 2,002' East from Southwest Corner Section 9, T7N, RgW, Seward B & M LOCATION AT DEPTH: 1,114' South and 124" East of Surface ELEVATION: 138' K.B. R. 'M. McKinley / Area Engineer. DRILLED BY: Brinkerhoff Drilling Co. Rig #59 DATE COMMEN6ED DRILLING: i:Q0 PM, May 22, 1975 DATE COMPLETED: Septembe~ 16, 1975 DATE OF INITIAL PRODUCTION: September 17, 1975 SU>giARY TOTAL DEPTH: 11,030' PLUGS: 11,030'-11,010' EFFECTIVE DEPTH: 11,010' CASING: 10 3/4", 40.5# Buttress K-55 cemented at 3~395' 7 5/8" cemented at 9,712' · LINER: S.To 1,509' of 5 1/2", 20# 8rd N'80 Top 9,519' Cemented at 11,028'. S.T. hole (24-9) Plugged at 9,921' 8/23/75 Fish 10,552'-11,056' Plug ]_0,552'-9,921' Perforations: Four 1/2" jet holes per foot ]0,882'-10,835' 10,845'-10,884' 10,894'-10,910' Logs____L Schl~erger ~Dual Induction Log ~Borehole Sonic Proximity Log - Microlog Formation Density ~Compensated Neutron Saraband Sandstone Analysis Dresser Atlas Acoustic Cement Bond Log Cement Bond Log 9,712'-10,542' 9,717'-10,546' 9,710'-11,020' '9,710'-11,016' 9,710'-11,016' 9,710'-11,010' 9,500'-11,000' 3,000'-9r702' 9,712'-11,017' 9,708'-11,017' INITIAL PRODUCTION Method: F16wing S~ptember 17, 1975 Oil: 1224 B/D Water: - B/D Gas: 280 MCF/D GOR: 228 CF/D (Lower Hemlock 8 sd only) May 22, '1975 Commenced operations at 1~00 PM. Drilled 15" hole !59'-620' ~ay 23~ ~1975~ Drilled 15" hole 620'-2,334' '.Ma~, '24, 1975 Reamed tight spots Drilled 15" hole 2,334 '-3,260' (561') 72 pcf mud .. (1,714 ') 79-85 pcf mud (92~') ' 79 pcf mud 'May. '25, · 1975 · · Drilled 15" hole 3,260'-3,425' (165') Circulated 150 sec. viscosity pill around to get g.ood cleanout. Run 10 3/4" casing. 79 pcf mud '.M~.,~ 26,'1975 Landed 10 3/4" casing at 3,395'° Cemented 3,395' of 10 3/4", K-55, 40.5# casing to surface with 1,300 sacks° Good returns. Welded 10 3/4" casing head. May 27,'1975 Installed and tested Class III 10" BOPE. 71 pcf mud May 28, 1975 Drilled out cement stringers with 9 7/8" bit from 2,700' to 2,790'. Drilled out float collar at 3,355' and float shoe. Drilled 9 7/8" hole from 3,398'-3,486'. May 29,1975 Drilled 9 7/8" 3,486'-3,992' . (506') 76 pcf mud ~May 30, 1975 Drilled 9 7/8" hole ,3,992'-4,294' . (302 ') . 78 pcf mud Drilled 9 7/8" hole 4,294'-4 708' Reamed (414 78 pcf mud *June 1,'1975 Drilled 9 7/8" hole 4,708'-5,243' 'June*2,*1975 Drilled 9 7/8" hole 5,243'-5,775' · . _ June*3,*1975 Drilled 9 7/8" hole 5,975'-6,171' June 4, 1975 Drilled 9 7/8" hole 6,171'-6,563' (53.5') (532 ' ) (396'~ ) . (392 ' ) 78 pcf mud 78 pcf mud 76 pcf mud 77 pcf mud *June 5, '1975 Drilled 9 7/8" hole 6,563'-6,972' 'June'6;'1975 Drilled 9 7/8" hole Dyna-Drilled 6,972'-7,084' 'June 7, '1975 Drilled 9 7/8" hole 7,084'-7,438' (409') (112 ' ) (354 ' ) 84 pcf mud 84 pcf mud 88 pcf mud June ~ 8, ~1975 Drilled 9 7/8" hole .7~438'-7,661 ' (.2231') 88 pcf mud June ' 9, ' 1975 Drilled 9 7/8" hole 7,661'-7,885' (224') 88 pcf mud 'June'10, 1975 Drilled 9 7/8" hole 7,885 ' -7,929 ' Dyna-drilled 'June ' 11, 1975 Drilled 9 7/8"~hole 7,929'-8,161' (44') 87 pcf mud (232') 88 pcf mud 'June ' 12 ," 1975 Drilled 9 7/8" hole 8,161 '-8 ~ 281 ' ; 'June ~13, '1975 Drilled 9 7/8" hole 8,281 '-8,571 ' (120') 88 pcf mud (290') 88 pcf mud June..!4 , .' 1975 Drilled 9 7/8" hole 8,571'-8,841' Dyna-drilled 'June ' 15, '1975 (270') 89.5 pcf mud Drilled 9 7/8" hole 8 ~ 841 ' - 9,050' (209') . 90 pcf mud 'J~u~. e 16~ '1975 Drilled 9" 7/8" hole 9,050 '-9,372 ' .(-322 ' ) Mud was-Gas cut to 81 pcf coming 'out, then to 87 pcf. Took Water kick of 20 bbls. at 9,343'° Viscosity up to 80 sec. Cut viscosity and added bar to mud to bri.ng up weight to 89 pcf. June 17, 1975 Drilled 9 7/8" hole 9,372 '-9,462' Dyna-drilled (90') " 90-87 pcf mud June 18, 1975 Drilled 9 7/8" hole 9,462'-9,545' (83') Gained 25 bbls., raised pump speed to 65 SPM and pressure to 2,400 psi, but could not hold back water. Shut well in. Built mud weight to 93 pcf with choke open and circulating. Drill pipe pressure suddenly fell from 1,100 psi to 800 psi° Closed choke, but left on pump, broke down forma- tion and pumped away 50 bbls. mud before shutting down pump. Continued to circulate through choke° Well dead with 94 pcf mud. Drilled 9 7/8" hole · 9,545'-9,565' (20') 94' pcf mud June 19,~ '1975 Drilled 9 7/8" hole 9,~65'-9,718' (153') 94-95 pcf mud · 'June ~20, '1975 Drllled 9 7/8" hole · 9,718'to 9r722' (4') Circulated and conditioned mud° Crew walked off job. Using supervisors, ran in hole and circulated and conditioned mud. 95.5 pcf mud June 21, 1975 Raised mud weight to 97 pcf to' control water entry. Layed down all drill collars and tools o ~ 97 pcf mud June 22, '1975 Rigged up to run 7 5/8" casing. Ran 7 5/8" casing with shoe at 9,712' and float at 9,635' and stage collar at 7,869'. Used 20 cu.ft. Water ahead, then 240 sacks of "G" cement and displaced with 2,693 cu.ft, bumper plug. 2 Jts. Casing (cut) 98 Jts. Casing 46 Jts. Casing 86 Jts. Casing Float Collar 2 Jts. Casing Fillup Differential Shoe 97 pcf mud' 7 5/8" Casing Detail 59.50' 33.7# P-110 Buttress 4077.78' 26.4# N-80 Buttress 19~3.80' 29.7# N-80 8rd LT & C 3574.46' 33.7# P-110 8rd LT & C 1.73' Top at 9635' 72.35' 33.7# P-il0 8rd LT & C 2.38' 9712.00' June '23~ '1975 Opened 7 5/8" stage collar at 7,869'. Circulated hole clean, no cement in returns. To cement through stage Collar, mixed 620 sacks of Class "G" i!cememt with 0°75% cfr2 and 2o1% gel using Water. Released closing plug ~and displaced cement with 2,070 cu. ft of fluid Closed stage collar !with .3,000 psi,~ held ok. Preceded cement with 20 cu.ft. Water. Started mixing at 8:20, C.IoPo at 9:10o Closed casing rams. Crew knocked off for i day at 9:30 AM. Rig on standby at 6:00 AM. 97 pcf mud June 24, · 1975 Landed casing and installed tubing head. Landed donut with plug and tested to 3,000 psi, ok. ~g on standby at 8:00 PM. 97 pcf mud June '25., '1975 Removed BOPE. Rig on standby at 8:00 PM. June '26, ' 1975 Started laying down drill pipe° Rig on standby at 7:00 PM. · 'June '27; '1975 Cleaned storage tanks and mud pits° June 28, 1975 Cleaned rig floor. Rig released at 8:00 PM. June 29 - July'30, '1975 On standby due to strike° · July 31,'1975 Started rig at 12:00 noon. Installed and tested 10", 5,000 psi, CLass III BOPE. ~ · 'August '1, '1975 rDrilled out stage collar at 7,868'. Tested casing to 3,000 psi, ok. Drilled out float collar and cement 9,635'.-9 702' Tested casing to 3,000 psi, ok Circulated and conditioned mud. 84 pcf mud .A.ugust '2 ~ 1975 Ran Acoustic Cement Bond Log 9.,.702'~3,000'!. ~'48 sec. Drilled' out shoe at 9,712': 'August'3;'1975 Drilled 6 3/4" hole 9,712'-9 921' (209') Conditioned. mud to 88 pcf and 88 pcf mud 87 pcf mud · . ug st '4, '1975 Drilled 6-3/4" hole 9~921'-10,022' {10.i') 86 pcf mud 'August '5, 1975 Drilled 6 3/4" hole 10,022'-10,205' ~ 'AUgUSt ' 6~ 1975 Drilled 6 3/4" hol.e ld, 205 ' -10,364 ' 'Aug~u_st · 7, 1975 Drilled 6 3/4" hole 10,364 '-10,533' (183 ' ) (159 ' ) (169 85 pcf mud 84 pcf mud 81 pcf mud · August · 8; 1975 Drilled 6 3/4" hole 10,533'-10,667' (134 ' ) 77 pcf mud '.A3_gust 9, 1975 Drilled 6 3/4" hole 10,667' -10,761 ' (94.') 77-78 pcf mud · Au~ust .10, .1975 Drilled 6 3/4" hole 10,761 '-10,856' (95~') 78 pcf mud August 1]., Drilled 6 3/4" hole 10,856'-11,000' ( 144.' ) 77-78 pcf mud August ]_2, 1975 Drilled 6 3/4" hole 11,000-11,056' (56') Pipe became stuck° Still had good circulation. Began to increase mud weight. Spotted 10 bbls. of lease crude around bit leaving 10 bbls. in drill pipe. Well started flowing. Controlled kick and raised mud weight from 52 to 79 pcf. Still getting some flow. All flow seems to be fresh water. -. 52-79 pcf mud August 13; 1975 Raised mud wefght to 84 pcf, well still flowing 1 bbl/day. Raised mud weight to 8505 pcf and well was static. Found pipe stuck from 10,212'- 11,056'o Backed off at 10,212' and left 844.3' fish in the hole. 85 pcf mud August 14, 1975 Spotted 20 bbls diesel with 10 bbls. outside and 10 bbls. inside. Pipe stuck at 1~,670'. CircUlated out Oil pill. 85.5 pcf mud August'15; '1975 Ran in hole and encountered top of 'fish at 10,626'. Hooked onto fish and recovered 414'o Reentered, screwed into fish, could not free and backed off. 86.5 mud 'August 16, 1975 Fishing August 17,'1975 Washed over fish from 10,626'-10,781'. While pulling, stuck pipe at 10,735". Pulled out leaving six joints of wash pipe ....... ? August 18, 1975 Entered hole, screwed into fish, mandrel.parted leaving 504' of fish in hole top at 10,552' bottom at 11,056' (see attached) August '19, 1975 Ran in hole and recovered fish. Circulated'hole Clean and prepared for logging. 87 pcf mud August 20~ ~1975 Schlumberger Dual Indiction Log 9,7i2'-10,542' and Borehole Compensated Sonic Log from 9,712'-10,546'o Pulled out. Reentered with drill pipe hung at 10,543', mixed 76 sacks of Class "G" cement with 3/4% D-31 slurry; weight, 115 pcf. Displaced cement with 424 cu. ft. of Water and mud. Reversed out 1.5 cu.ft, cement, lost 12 bbls. of mud. 88 pcf mUd August 21, 1975' Ran into hole, found cement at 10,435' and pulled up to 10,143' and cir- culated. With drill pipe hung at 10,143', mixed 82 sacks of class "G" cement, with 75% D-31 slurry; weight 117-123 pcf. Preceded cement with 40 cu.ft. Water and mud followed by 9 cu.fto Water. Displaced with 445 cu.ft, mud° Cement in place at 5:25 PM. Backed off to 7 5/8" shoe at 9,712' and reversed out approximately 40 cu. ft. of cement. Conditioned mud, opened pipe rams, well flowing muddy Water. Water cut to 85 pcf. Circulated mud weight to 89 pcf. Pulled out of hole. 89 pcf mud August 22, 1975 Entered hole and found cement at 9,990' - circulated. With drill pipe at 9,990', mixed 74 cu. fto of Class "G" cement with 75% D-31 slurry; weight 123 pcf. Displaced cement with 404 cu.ft, mud and Water, cement in place at 10:20 PM. Pulled to shoe, reversed out cement and conditioned mud. 89 pcf mud 'August 23, 1975 Ran in hole and found top of cement at 9,818'o Drilled hard cement to 9,921' - circulated hole clean. Made up Dyna-drill and checked B.O.E. Reentered hole, oriented and Dyna~drilled and~-sidetracked from 9,921'- 9,945'. 89 pcf mud 'August 24 ;.'1975 Drilled 6 3/4" hole 9,945'-9,969' 'August '25, '1975 Drilled 6 3/4" hole 9,969'-10,102' . (24:') (133 ' ) ':' 89 pcf mud 89 pcf mud 'August '26, 1975 Drilled 6 3/4" hole 10,102'-10,179' August'27,'1975 Drilled 6 3/4" hole 10,179'-10,204' Pulled and checked BOPE. 28, '197%, (77') (25") Changed bit to 6 5/8"° Reentered and drilled 2' to 10,206' where teleorienter failed. 'August '29, ' 1975 89 pcf mud 89 pcf mud 89 pcf mud Drilled 6 5/8" hole 10,206'-10,209' (3')_ 89 pcf mud 'AugUst'30, 1975 Drilled 6 5/8" hole 10,209'-10,234' ' ugus ' '1975 Shut down due to strike. from 10,234'-10,286' (25'). 88 pcf mud Returned to drilling and drilled 6 5/8" hole (52') o Pulled out of hole. 'September *I ~ '1975 Checked Dyna-drill, BOPE then entered hGle and reamed 6 5/8" hole to 10,384 '. .Septembe~r '.2, '1975 Drilled 6 5/8" hole 10,384'-10,441' September · 3, 1975 (5.7.') '~ 89 pcf .mud Check BOPE, oko Drilled 6 3/4" hole 10,441'-10,598' (157') 89 pcf mud Septemb~..~r ' 4L ' ~1975- Drilled 6 3/4" hole 10,598'-10,718 ' '_September '5, ' 1975 (120.') .. 89 pcf mud Drilled 6 3/4" hole 10,718'-10,831' (113') 89 pcf mud · September '6, '1975 While drilling pipe stuck approximately 30 minutes. Continued drilling f~om 10,831 ' -10,936 '.. (105 ' ) 89 pcf mud ; 'September'7;'1975 Drilled 6 3/4" hole 10,936'-11,030' (94') 89 pcf mud September '8, '1975 Pulled out of hole and rigged up to run Schlumberger logs. Ran Dual Induction Log 9,712'-11,017' and Borehole Compensated Sonic 9,708 '-11,017 ~ . .Se.pr.ember '9 t '1975 Continued log run with Proximity Log-Microlog 9,710'-11,020' Formation · f Density Log 9,710'-11,016', Compensated Neutron Formation Density Log 9,710'--11,016'. Conditioned hole for 5 1/2", 20# liner. Landed lines at 11,O28', top at 9,519'. Cemented with 400 cu. ft. of Class "G" cement with .75% CFR-2. Bumped plug was tested with 3,000 psi° · 89 pcf mud ' '.September ' 10, '1975 Ran in hole and drilled cement from 8,450.'-9,519'. Tested liner lap at ~9,519' and 7 5/8" casing oko~ '~ ~eptember'll, 1975 88 pcf mud Ran in and drilled out cement from 9,523''9,546'° Completed cleaning out hard cement to 10,951'o. 89 pcf mud · ~eptemb.er · 12_, 19_75 Drilled out hard cement from 10,951'-11,010'. Circulated and rigged to run Cement Bond Log° 70 pcf mud ' 'S_eptember · 13, ' 1975 Completed Cement Bond Log from 9,500'-11,000'o Perforated from 10,822'- 10,910' with four 1/2, jet holes/foot. Ran two 5 1/2" scrapers, cleaned out and circulated. 70 pcf mud · 'September 14, '1975 ; Rig up Hydro test and ran 2 3/8" x 3 1/2" tubing as per program. attachment). (see ' 'September '15, '1975 Completed running production tubing as programmed (see attached). Ran Dresser Atlas Neutron Log to check packers. Closed blind rams, pressure. tested Cosasco plug to 3,000 psi, ok° Nippled down B.O.P. and installed x-mas tree. '.S.eptember 16, 1975 Tested x-mas tree to 5,000 psi, eke Pulled Cosasc0 plug. Changed over to Oil. Ran Brown blanking plug set in "D" nipple at 10,893' and pressure tested up to 3,500 psi° Packer set at 10,886', 10,83.6' and 10,804'. Rig down and released rig at 9:00 PM. J. W. Wilson 0 41 I I I,O~4, _ ~c_. I/ II I ~ ~" , ~ ~ ~ 1,4.~ ~ aY4" z so,lq .~,~.~ a.q~ ). ZCL.~ x2 4 ELI~V. 138, KB 4137' 606l' ; · ,. 9519' 2330.h2' -- h,o32,,gg' - K.Bo TO LAI'~DIN G M. - T. ubing tlunger hl JT$. 3%f' 9°3# EUE 8rd N-~O tgojlRESS ~'~2~'97r p C/~iCO D; MANDREL '' '"' ~2 JTS. 3~' 9~ EUE 8rd N-50 BUTTRESS ' 20 J~. 3~" 903~ EUE 8rd N-80 BUTrRFS~ 6',~50.09' ~ Ct~CO ~.~.~ MANDREL 1~ JTS. 3~" 9,3~ EUE 8rd N~80 BUTYRE~' 16-a%. 3~' 9.3// gUgAdrd N-80 BU'rTRE~ 7~ ~86037 ' ~ C~CO MM i~NDREL 7 JTS. ))ff' ~5# EUE 5rd N-80 ~TERE~ ) CAMCO Y2~ M~.NDR~ 9,373 o3h ' - F.C. 9635' 37 JWSo 3~' 9.3# gus 5rd N-80 BUTTRE£S ) 2~". x 3iF' EgE 8rd X-OVER [i6 JTS, 2~" lio 7// EUE 8rd }{.-.80 TU BINO ~0,801,.~1' i 2~" OTIS "XA" SLEEVE 10,80~o39' .~ 2.~g, x 5~" 20# BAKER "FH" PACKER .~[22' '10,510.~' ~ 2~" OTIS "S" NIPPY, Position ~3 .2~g'' BLAST J T. ~ .... ZO,~36.70, ~ 2~" OTiS "XA" SL~V~ 2- x 5~" 2~ B~ER "FH" PACK~ 10845' -10~8h2.87' ~" 2:~ OTlo S NZPP~ Posl~5on ~2 ~to884' - ~0,8d30~3~ ~. ~ x 5~ 20# BAKER I,H PACKgR tOS' 10,5~2.10' ~;~" ' '~'"' "'" 3 I1 II Ii t ~2-.~ CMflCO D NIPt ~ ioglo' --10~[0,69~ ~ ~" BAKER SIIEAR OUT SUB TOP OF PLUG 11~O10~ ~/P TI; 11~O30, 9,10 16 93 9o73 10!6 9~72' h63 9.11, 9oO6' 215~bO' 9=12' 1152. 11,26.82 ' 2o88, 6o1~, 1o52, 1.hh, 2o88, 6o17, 1.52, 37°3/4' 1.h0, 6.16' ,93' l? o cO ' .60' SCU 24A- 9 CASING &TUBING DgTAIL SECTION 9 TTN., R. gw. OCT. 7,5 il o 0() ' 2 2dr} ~. 55 C(~MP1, ETION REPORT - NEW WELL STAI?DARD OIL COMPANY OF CALIFORNIA, WESTEt:~N OPERATIONS. INC., OPERATIONS AI~£A: ,~ - ~- owanoon River Field LANB OFFICE: Anchorage Kenai Peninsula Alaska PROPER;I?Y: Soldotna Creek [Init LEASE NO: A-028997' WELL' NO: 24A-9 AP1 NO: 50-133-20273 .. LOCATION AT SURFACE: 2,~41' North and 2,002' East from Southwest Corner Section 9, TTN, Rgw, Seward B & M LOCATION AT ])EPTIt: 1,114' South and 124' East of Surface ELEVATION: 138' K.B. R. M. McKinley / Area Engineer DRILLED BY: Brinkerhoff ) ' ] '~- [rz.lz..~ Co. P&g ~59 DATE :CoMMEN~ED DRILLING: 1 :QO PM, "May 22, 1975 DATE CO~[PLETED: Septe~e~ 16, 1975 DATE OF INITIAL PRODUCTION: September 17, 1975 TOTAL DEPTIt: 11,030' EFFECTIVE DEPTlt: 11,010' 'CASING: SUI~iARY PLUGS: 11,030'-11,010' 10 3/4", 40.5# Buttress K-55 cemented at 3,395' 7 5/8" cemented at 9,712' LINER: S. 1:. 1,509' of 5 1/2", 20#.Srd NL80 Top 9,519' Cemented at 11,028'. · . S.T. hole (24-9) Plugged at 9,921' 8/23/75 r. ~_.~, 056 ' Fish ].0,.~..~... -2.1, Plug ].0,552'-9,921' Form 10-403 Subml t "I ntentions" in Triplicate REV. 1-10-73 ~_~ & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL I......I OTHER 2. NAME OF OPERATOR Standard Oil Company of California, WOI 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 7-839, Anchorage, Alaska . 99510 SCO 24-9 4. LOCATION OF WELL At surface 2441' North and 2002' East of SW corner of Section 9. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 12. PERMIT NO. G. L. = 119.7' 14. Check Appropriate Box To Indicate Nature of Notice, Re 3orr, or Other Data 5. APl NUMERICAL CODE 6. LEASE DE51GNATION AND A-028997 7. IF INDIAN, ALLOTTEE OR TRI 8. UNIT, FARM OR LEASE NAME Soldotna Creek 10. FIELD AND POOL, OR WILDC Swanson River F!LE: SEC.,T., R.,M.,(BOTTOM HOLEOBJECTIVE) Sect. 9, T7N, R9W NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Sidetracking (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Due to stuck drill pipe at 11,056 the original hole was abandoned; top of cement plug is at 9921' with D.P. fish 11056 - 10508'. The well is presently being sidetracked below 9921' to a bottomhole location approximately 150' from original hole. The well is to be designated 24A-9. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: ..... TITLE--- Area' Engineer. DATE R/26/75 T IT LE DATE See Instructions On Reverse Side Submit "1 ntentions" in Triplicate .: & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OwiELLL [-~ GAS [---] OTHER WELL 2. NAME OF OPERATOR Standard Oil Company of California, W©I ADDRESS OF OPERATOR P. O. BOX 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 2441' North and 2002' East of SW corner, Section 9, T7N, R9W, SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) G. L. = 119.7' Check Appropriate Box To Indicate Nature of Notice, Re 14. 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. A-028997 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Soldotna Creek 9. WELL NO. 24-9 10. FIELD ANDPOOL, OR WILDCAT _ Swanson River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 9, TTN, R9W 12. PERMIT NO. 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) SUBSEQUENT REPORT OF: PULL OR ALTER CASING WATER SHUT-OFF ~ REPAIRING WELL MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* CHANGE PLANS (Other) Suspend (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Drilling operation3 were discontinued at 9722' as a result of the labor strike that started on June 20, 1975. The 7 5/8" casing was cemen~ were suspended. The hole stands full of mud. ,J DIR ~ two stages and the operations C, ENG ~_4~~''~'' ., TITLE . , 16. I hereby certifY that~e foregolng~j~ t/ue and correct SIGNEDJ~-/".~~ , / (This space for State office use) j 2 ENG 3 ENG 4 ENG 5 ENG 2 GEOL --i-3 GEOL I R~v I DRAFT ) SEC CONFER: FIJ. F; 110 Area Engineer June 30, 1975 DATE APPROVED BY . . CONDITIONS OF APPROVAL, IF ANY: TITLE DATE ... See Instructions On Reverse Side 1~ ~o. P--4 STATE oF~I. ASKA OIL AND GAS CONSERVATION CON~rI-I'EE SUBMIT 1~ DLr?LICA~ MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS X~'~LL __ NA.ME OF OPIgI~TOR Standard Oil Company of Californiar WOI ~ ADDZESS OF OP~TO" P. O. BOX 7-839, Anchorage, Alaska 99510 LOCA~ON OF W~L,L 2441' North and 2002' East from the Southwest corner of Section 9, T-TN, R-gw, SB&M. 5 At)I NL~A{ERICAL CODE ~0-]33-20273 ..... ~ LF-~ASE DESIGNATION A~'D SE]RIAL NO. A-028997 ? IF INDIAN. A~DY'iF, I~. O~ TRIBE 8. L~IT FARM OR ~.~ASE NAJ~E Soldotna Creek 9 WELL ~O SCU 24-9 Swanson River - Hemlock SEC , T.. R. M ~O~OM HO~ o~rvFO Sec. 9' T-7N, R-9W, SB&M 12. PE~RA~IT NO 75-22 13. REPORT TOTAL DEP1TM AT F2qD OF MON,~TM. CI{;uNC]F~S IN HOLE SIZE. CASING A~) C~NTING JOB~ INCLUDING DEPTH SET A~ VOL~ USED p~ORATIONS. ~TS ~ ~SULTS FISHING JO~ JUnK LN HOLE AND SIDE-~ACKED HOLE AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ Co~ITIONS May 1975 Cemmenced operations May 22, t975. Drilled 15" hole from 59' to 3425'. Cemented 10 3/4", 40.5#, K-55 casing at 3395' with 1300 sacks of class "G" cement. Install class III BOPE and tested ok to 2500 psig. Drilled out cement 3355' to 3395', cleaned out to 3425' and drilled 9 7/8" hole to 4708'. · %.),L AND GAS AR?CHORAC~ 14. h form i oil and gas coneervotion committee by the 15th of the succ~ding month, u~l,t~ ot~erwi~a ~r.~cted. TRANSMITTAL AN CKNOWLEDGEMENT OF RECEIPT OF :~zAL- (ALASKA) DEPT.: PLACE: DATE ~~.~ ~'~2/~TJ- FD - Folded R - Rolled S - Sepia F - F±lm X - Xerox B - Bluel±ne THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMi~EDIATELY. COMPANY WELL HISTORY LOG 2" 5" ! I " " " " .,; t.. ,,,. il;;L3 -O!~.($1(..N C F OIL AND GAS RECEIVED BY REMARKS O~//OTHER biDE, THIS sH~--~T WELL NO. SCU 24-9 SECTI ON NO. 9 TI~ACT NO, E:] PROPOSED } F-1 PREL IHIttARY ~_3 FINAL WELL SURVEY Pro-312 C-i~NTy OF Kena i ClTY'-~F_~~~'~<~ _ TOWNSHIP 7 N RANGE 9 W ~]S,B.~ & H. E:] H.D.B, & H. LOT NO. FI ELD Soldotna Creek Uni 2002 ft. Easterly at right angle from West boundary of Section 9, and 2441 Northerly at. right angles from South boundary Section 9,' LO CA T I ON T 7 N, R 9 W, S.M. ELEVATION: GROUND 1 ]9.7 C~CRETE HAT DERRICK FLOOR ' ALTERNATE OR SURVEYED LOCATION LOCATIO~1 DESIGNATION LOCATION COORDINATES HOVE REMARK8 ,, . Final N 22, 087,695.02 E 2,021,875.18 ,, , , ,, NORTH I , I ~ Sec. 9 --4- 20021 + ., SOUIH . Top of No SKETCH OR REMARKS Location given is to center of existing 20" conducter in bottom cel 1 a r. ~th Rim C.M.P. Cellar Elev. 119'68 , , , STATION BLARING DISTAI~CE SINE COSINE NORTH SOUTH EAST WEST , , C.C. DIV. ENGR. FILE PIINTID IN SURVEYOR Gary Drasky IqAINT. FRHN. DATE May 13, 1975 DATE HAINT. $UPT, DATE PRO.312 (2500.CD* 1- 58) -' WELL SURVEY Pro-312 '~ COUNTY OF,, Kenai CITY OF TOWNSHIP 7 N RANGE 9 W r-Xl S.B.~. & X. 1"1 H.D.B. & H. LOT NO. FIELD Soldotna Creek Unit 2002 ft. Easterly at right angle from West boundary of Section 9, LOCATION and 2441 Northerly at right angles from South boundary Section 9, T ] N, R 9 W, S.M. ELEVATION: GROUND 119.7 CONCRETE HAT DERRICK FLOOR ,, ALTERNATE OR SURVEYED LOCATION LOCAT I ON DES I G#ATI ON LOCATION COO RD I NATES HOVE RENARKS ,, Final N 22, 087,695.02 , E 2,021,875.18 , ,. · NORTH , ' i Sec. 9!, 2002i + ' ' .... + ......... 4- .... ' _ I . $OUIH BEKCH HA RK I S: . I I I Top of No' SKETCH OR REHARKS Location given is to center of ~,~ Or ~- '~ existing 20" conducter in bottom cellar. ' · th Rim C.M.P. Cellar Elev. 119.68 STATION BE;~R I.G DISTANCE: SINE: COSINE:" NORTH SOUTH r~ST · WEST ,, Iil ' DI\q~C N i;.F OIL ¢ ND GA5 a ~ ~ A m ,, , , , , , C.C. DIV. ENGR. FILE SURVEYOR Gary Drasky 14AINT. FP, NN. DATE May 13, 1975 DATE HA INT. SUPT. DATE PR0.312 (2500.CD. 1.58) J/ELL NO. SCU 24-9 SECTION NO. 9 TRACT NO, I:3 PROPOSED } I::::] PRELIMINARY ~:~ FINAL WELL SURVEY Pro-312 Kenai CITY OF FI ELD SO1 dotna' Creek Unit 2002 ft. Easterly at right angle from West boundary of Section 9, COUNTY OF., ,TOWNSHIP 7 N LOT NO, and 2441 Northerly at right angles from South boundary Section 9, LOCATI ON T 7 N, R 9 W, S.M. ELEVATION: GROUND 1 19.7 CONCRETE HAT DERRICK FLOOR ALTERNATE OR SURVEYED LOCATION Loc~;TIO# DESIGNATION LOCATION COORDINATES .... MOVE REMARKS , Final N 22, 087,695.02 E 2,021,875.18 · , .. · · .f NORTH I ' I ~ Sec. 9 2002i + ' _} ! BENCH HARK I$: SKETCH OR REHARKS Location given is to center existing 20" condu~..,, ~,,, Top of No:'th Rim C.M.P. Cellar Elev. 119.68 STATION SEARING DISTANCE SINE COSINE NORTH SOUTH EAST WEST , , , , ! C.C. DIV. ENGR, FILE ~llll~ll l# U,I,I. SURVEYOR Gary Drasky HAINT. FRHN. DATE May 13, ]975 DATE NAINT. SUPT. DATE PR0.312 (2500.CD. 1.58) March 28, 1975 Re: Soldotna Creek 24-9 Standard Oil Co. of Calif.,Operator Permit No. 75-22 Mr. R. ~cKinley Area Engineer Standard Oil Co. of California Dear Sir: Enclosed is the Approval appl.!catton for permit to-drill the above referenced well, on or about April 15, t97'5, at a location in Section 9, Township 7tt, Range gW, Well samples, core chips, and a.mud log are not required. A directional sur- vey is required. Prior to cessation of drilling operations a registered sur- vey pl at i s requi red. The class III BOPE, except hydril, on 7-5/8" casingPmust be tested to ~Og rather than 2500 pstg using a test plug. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in t~e areas are subject to AS 16.50.870 and the regulations promulgated thereunder {Title 5, Alaska Administrative Code). Prior to eommenci, ng 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 03, Article 7 and the regulations promulgated thereunder (Title 18, Alaska lklmtnis'trattve Code, Chapter 70} and by the Federal Water Pollution~.Comtro! Act., as .~memded. Prior to commencing operations you may be con~cted by a representative'of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases., the Alaska Department of Labor is being notified of the issuance of this permit to drill. Very truly yours, O. K. Gtlbreth, Cha i rman Alaska Oil and Gas Conservation Committee Enclosure OKG:be Mr. R. McKinley -2- ~rch 28, 1975 cc: Department of Fish and Game, Habitat Section w/o enct. Department of Environmental C~nservatimq w/o encl, Department of Labor, Supervisor, Labor Law Dtvlsion w/o encl. Form 10-- 401 R~V. I--I--?1 TYPE OF WOBK STATE OF ALASKA OIL AND GAS CONSERVATIO'N ,COMMITTEE PERMIT TO DRILL OR DEEPEN SUBMIT IN 'P~[ ATE (Other mstructioh~n reverse side) DEEPEN DRILL [X] b. TYPEOF WmLL o,,. [] °'" r-I ,,NOLE [] F__] WELL WELL OTH~J ZONE ZONE 2 NAME OF OPEI~ATOR Standard 0il Company of California, W0! 3. ADDRF. M80~ OPF--AttATOR P. 0. Box 7-839, Anchorage, AK 99510 4. LOCATION OF WELL , - At surface Approximately 2580'N and 1890'E of SW corner Section 9, T7N, R9W, SB&M At p,-o~sed prod. ~.o,e Approximately 1250'N. and 2050'E of SW corner Section 9~ T7N.~ R9W~ SB&M 13. DISTANCE IN MILES AND DIRECT[ON FROM NEAREST ToWN OR POST OFFICE* 15 miles approximately 14. BOND INFORMATION: .S. t .a ~ewi .de, ii 451636 TYPE~anzonwmae su~e~y ~.d/or No. SL 6205862 J AP! #50-133-20273 6. LEASE D~IGNATION A2q'D S~tlAL NO. A-028997 1. IF IN'gIAN, ALLOTTEE OR TI~LBE NAME 8. UNIT FARM OR LEASE NAME Soldotna Creek ~. WELL NO. 24-9 10. FIELD AND POOL, OR WILDCAT Swanson River !1. SEC., T., R.. M., (BOTTOM HOLE OBOECTIVE) Sect 9~ T7N~ R9W, SBM 1~. $100,000 $$50 ~ 000 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION* TO NEARES%' WELL DRILLING, COMPLETED. OR APPLIED FOR, FT. t16. NO. OF AcRF-~ 1N LEASE- 1'. PROPOSE~ DEPTH 11,081 17. NO. ACRES ASSIGNED TO THiS WELL 8O 21. ELEVATIONS (Show whether DF, RT, CR, etc.~ 128' Ground Level 23. PROPOSED CASINO AND CEMENTING PROGRAM ~0. ROTARY OR CABLE TOOLS · Rotary 22. APPROX. DATE WORK WILL START* ,, .April 15, 1975 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH quantity of cement _ ., , , , *We propose to drill a new oil producing well per attached program. Note: Administrative approval for this location will not be required per telecom Messrs. Hamilton- Dakessian on March 18, 1975. LL. IN ABOV~ SI~'AClg ~CRIBE FROPOSED PROGRAM: If ~1 is to dee~n giv~ ~ on ~r~sen~ ~u~iv~ zo~ ~:~~/~ ~w preclusive ~n~. _l~.r~l i~ ~ ~rll[ or ~n ~o~11~, give ~memt ~' on ~bSu~a~ ~t~ ~d mea~ ~'~ ' ~ ~ ..... re.leal dep~.~lv~ blo~reve~ter p~gFam. ~4. I hereby ce~ife~~~~~' o ' e an~ Corre~ s~o,~ /! ~.~~~~--, n.~ March 18, 1975 ~ Area Engineer , , (Thi~ space for S~te office u~) CONDI~ON~ O~ ~P~V~, IP A~~ SAMPL~ AND CORE CHIPS H~U~ J MU'D LOC ~ ~U~: a Y~ ~NO J, m Y~ ~No SEE TRANSMITTAL LETTER DI~ION~ SURVEY R~~ A.P.I. ~C~ COD~ ~=~.o_ ~- Z~ ~ov~.= March 28, }975 ] ~,, ~. Cha i rman ~o~ _ . ..... m~ March 28, 1975 ~ '*~ I.~o., ~ R,v,~ ~d, PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING P ROG RJM'Vl -- Field: Swanson River J, ~roperty a~ Well: Soldotna Creek Unit 24-9 Surface Location: Approximately 2580' north and 1890' east of southwest corner of Section 9, T7N, R9W, SB & M. Existing surface · ~ad for SCU 323-9. ~oposed Bottom H61e Location: Approximately 1250' north and 2050' east of southwest corner of Section 9, T7N, R9W, SB & M. · . Elevation: 128' G.L.; estimated 145' K.B. Blowout Prevention Considerations: 1. Potential Problems: A. Gas and Water Entries: Gas sands may be encountered at any depth below the shoe of the surface casing. Well 323-9 blew gas at 4552 and 6580, and had a 100 barrel water entry at " 7350 - 742. Well 34-9 had a high pressure water entry at 7560' requiring mud weight of 99 - 101'pcf, 'Caution should-be~-exer- cised not to swab'the hole on trips.. Gas and water entries can cause severe problems, and the mud system should be carefully monitored at all times. .. .B. Lost Circulation: No losses have been experienced during drill- ing operations in surrounding wells except while cementing the 7" casing in 34-9. However, lost circulation has occurred in other SRF wells while drilling the Hemlock with +98 pcf mud. In SCU 24-9 casing will be cemented above the Hemlock zone before m6d weight is reduced to penetrate the interval. C. Precautions: Any kicks Should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times, but especially not to hydraulic the formation and lose circulation while running in the hole nor swab the hole while pulling. An adequate supply of weight and lost circulation material should be at the well site at all times. 2. Maximum Anticipated Formation Pressure: Per formation tests in SCU 14A-9: _ ~ep.~h Zone Static Pressure APPROV .... PROGRA~ 10,663 LH8 4693 . 10,751 LH10 4901 The zones do not appear to be hydrostatically in b~nce. P~po~al for Well Operations PRO 316-1 · Drtllin9 Program · o, . ~lax~Anticipated Surface Pressure: 3800 psig. 'Prevention Equipment C~ass 111 5000 psi on 10 3/4" and 7 5/8" casing. 2. XzI~ta11 and ~e~tper "Operating Instructions D-17." 1. ]~rive 18" conductor Pipe to +80' or as deep as possible during ring up. 2. D~ill 15" hole to 3400'+. Maintain drilling fluid per the attached ~xilling fluid program. 3. Cement 10 3/4", 40.5#/foot, K-55, buttress casing at 3400'. a. Use float shoe and stab in duplex collar one joint up. · b. Lock bottom five joints of casing. Centralize the casing above the shoe. Cement through the shoe in one stage as follows: 1. Use sufficient Class "G" cement premixed with 2.4% gel by weight of water to obtain cement returns to surface. Basis: Yield of Class "G" + 2.4% gel by weight of water = 1.86 ft.3/sk. 2. If cement returns are not received at the surface, do a top ,ave stage collar on location in.case lost circu while drilling top hole. 4. Cut off 10 3/4", 40.5~/ft., K-55, casing below the top of the cellar (ground level) to allow the top flange of the tubing head to be above ground level after completion· Install 10" -5000 psi, 10 3/4", SOW casing head. Test welded lap to 2500 psi ~. Install Class 111, 10" -5000 psi, BOPE as per the attached BOPE 4esign. Test BOPE, kill line, blow line, and manifold to 2500 psi ...]3er "Operating Instructions D-17." ?.' Drill out the cement in the 10 3/4" casing with a 9 7/8" bit to within 10' of the shoe. Pressure test the 10 3/4" casing to not over 2500 psi. If test is okay, drill out the 10 3/4" shoe. Drill a 9 7/8~ hole to a true vertical depth of 10,405', est~ated '10,644' ~, estimated top of the Hemlock sands as follows: . · e. o a. Follow mud specifications per the attached mud program. Take single shot surveys to the estimated KOP at a minimum of -every'.480'. Should conditions-warrant, reduce the survey interval to every 240' or less. Always take a survey on a dull' bit. c. Beginning at approximately 7000', KOP., 'build 2°/100' to 23°33'. Lead well for ~ 10°+ right-hand turn. ' Along Course of 'S6°52'E, section is approximately 1340'. Target is the base Of the Hemlock No. 8 sand at a location approx~ately 2050' east and 1250' north of the southwest corner of Section 9, T7N, R9W. pROGRAM 9. At effective depth, condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run the following Schlumberger logs: .. a. Dual Induction - Laterolog from drilled depth to the shoe of the 10 3/4" casing. Use linear scale for the 2"=100' and logarithmic scale for the 5"=100'' Use 10+ bM SP scale and 0-50 ohm-meters for the linear resistivity ~cale. b. Have Sonic log, and Compensated Neutron-Density log on the location. Run Sonic log from T.D. to surface casing. Shoot S.W.S. in basal MGS "G" sand as warranted· Run Compensated Neutron Density thru MCS sands if warranted. Consider further · ~_~ evaluation of "G" sand if hydrocarbons indicated. ~1~. ill ahead as indicated by log run.to set 7-5/8" casing shoe at the ~t~p of the Hemlock (II-l). ' ll. Cement 7-5/8" castnS at the top of' the. Hemlock as follows: r-m.'.',q~C;-~[~! ' i'~ ": !~ ~ }'?* C A?~,~':~.~'~()[~.- ~'~ a. Casing details will be ~rnished when pipe become~ available. Design requirements are shown in PRO 316-A (attached), Proposal for Well Operations PRO 316-1 Drilling Program Run differen~ia'l'~'l~~,~and collar. . . Run stage collar at approkimately 7900'. d. Have triplex shoe on the location in case it is necessary to set the 7 5/8' casing above the drilled depth. e. Centralize the bottom 700' and above and below the stage collar at 7900'. f. Cement in two stages using Class "G" cement mixed with 2.1% gel by weight of water as follows: Shoe Job - Use sufficient cement-gel mix followed by 100 sacks of neat cement to reach 8700'+. 2. Stag~ Collar - Use sufficient cement-gel mix through collar at 7900' to reach 4500'+. 12. Remove BOPE and land the 7 5/8" casing. Install a 10" -5000 psi bottom flange x 10" '-5000 psi top flange tubing head. Test secondary packoff to 5000 psi. Install 10" -5000 psi BOPE. Test BOPE to 3000 psi per "Operating Instructions D-t7." %3. Drill out cement and stage collar and clean out to within 10' of the ? 5/8" shoe. 14. Run Variable Density-Cement Bond Log from th~ effective dept~ to above the top of the cement from the stage collar job. 15. Based on CBL, squeeze for WSO above the Hemlock as required. 16. Pressure test the 7 5/8" casing to 3000 psi. 17. Condition mud weight to 72-74 pcf. (72 pcf mud provides a hydro- static pressure Of 5335 psi at 10,670' VD versus 4695 psi est. resevoir pressure.) 18. Drill a 6 5/8" hole to true Vertical depth of 10,805', estimated 11,081' MD. (Total depth is projected 20' above the base of the Hemlock 10 sand). · . 19. Condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run and tape the following Schlumberger logs: a. Dual Induction - Laterolog from TD to the shoe of the 7 5/8" casing. Use same scales, as 'sbef°re'. b. Sp-BHC Sonic from TD to the hoe of the 7 5/8" ca~. Proposal for Well-~perations PRO 316-1 ' Drilling Program .. ~.. Microlog from TD to the shoe of the 7 5/8" casing. · d. Compensated Neutron-Density Log. 20. Condition hole for 5 1/2" liner. 21. Cement approximately 650' of 5 1/2", 20~, N-80 LT&C at TD as follows: a. Run float shoe and float collar. Do not use centralizers. Allow for approximately 200' of special clearance P-110 couplings in lap below the liner hanger. Use sufficient Class "G" cement treated with 3/4% CFR-2 to reach to above the top of the liner. Mix a heavy slurry to 118-122 pcf. 22. Clean out cement to the top of the float collar. Run Variable Density Cement Bond Log from effective depth to above top of the liner hanger. 23. Pressure test the 7 5/8" casing, 5 1/2" liner, 7 5/8" x 5 1/2" lap t° 3000+ psi using the rig pumps. 24, Production test the lower H8 interval{s)--to verify c-lean oil produc- tivity if the.log analysis indicates high water saturation. '25. Jet perforate'selected Hemlock 8 sand-intervals for production. Use 3 3/8" OD carrier guns loaded with four 1/2" holes per foot. 26. Run tandem casing scrapers and scrape the entire 5 1/2" liner. 27. Run and hydrotest to 5000 psi, approximately 10,800' of 3 1/2" x 2 3/8" tubing and gas lift mandrels. Run 2 3/8" OD tubing and jewelry in the 5 1/2" liner. A detailed completion program will be provided after TD logs have been run. 28. Remove BOPE and'install x-mas tree. Pressure test tree to 5000 psi. Displace the drilling fluid down the annulus and up the tubing string using lease crude oil. 29. set the production packers and release the rig. Place the well on production as directed by the Production Foreman. .. O/S f'EB28'i'5 RMM " Area Engineer O/S Ar~a Supervxsor ,L B. A. Dakessian APP~C~E-~-- PROGRAM DRILLING FLUID PROGRAM $CU 24-9 SWANSON RIVER FIELD BASIC DRILLING FLUID SY~ ~4edium treated lignosulfonate mud. OPTIMUM DRILLING FLUID PROPERTIES Mud Properties .(Vertical Depths) 0-3,400,~ 3,400' -6,000' Weight -pc~ ............ ~: Viscosity - sec/qt., API Fluid Loss - CC, API Plastic Viscosity - CPS Yield Point - lb./100 ft.2 Gel - lb./100 ft.2 - !0 m~n. Calcium - PPM S~lids Content - % Vol Max. 75# pcf As Required 6,000'-10,405" lO,405-TD 72 - 80 94 -- 10O 72 - 74' 40 - 60 43 - 48 43 - 47 7 -- 10 7 - X0 4 - 7 10 - 20 20 - 30 4 - 7 5 - 10 8 - 12 8 - 12 '10 max. 10 max. 0 - 5 8.5 - 9.0 -- 8.5 - 10 9.5 5mu%x.. 50 max. 8 - ~2 10 - 18 16 - 20 1. Drill %op hole to 3,400'4 with salavaged mud, if'available. -- . 2. Convert top hole mud to gel mud while drilling from 3,~00' to 6,000'. At 6,000', increase weight and have mud properties as listed in Colun~n No. 3 at 7,000'. 3. Use medium treated lignosulfonate mud below 6,000'. 4. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 5. Maintain an adequate supply of lost circulation material at the rig. · . 6.' Make a high pressure - high temperature fluid loss determination every third day. ~ake fluid loss tests at estimated bottom hole t~mperature 170~F~ Maintain total hardness under 100 ppm and report all versenate titration as CaCl2. PI]0P'0SAL FOR WELL'0PERATIOP S PFI0-316-A (TO BE USED AS A G0-111) CASING I,_.3UIR£MENTS PRODUCIr .._. EQUiP E. NT · -q~ 24-9 , , FIELD Su~n~nn R~vpr Field TOTAL DEPTH 1NRO5 VD METltOD OF PRODUCTION E~IMATED O~/G ~~/~ EQUIP. FOR STEAM CASING Gross Footaqe APl Size Weigh~ ~rab~ Conductor 80' ~8" ~04 ~ ~' WELL/LOCATION NO. · .. . ; · · Perforated CASING UNITIZED Gas lift Threads Line Pipe DATE __2/13/75 ESTIMATED SPUD DATE April l, 1975 MAX. ESTIMATED SURF. PRESSURE 3,800 INJ. PRODUCER x Coupling Computer Desiqn For: .562" Wall This Well Standard Design For Field Well No. Surface 3400' 10 3/4" 40 5 ' K-55 Buttress _- · · Requires: Float shoe, stab-~n duplex collar and sta~e collar w/buttress Max. Drift Angle . Thrds; 15 - 10 3/4" x 15" cnetralizers, 2 - 10 3/4" stop rings, Baker Loc. Water String: Design based on mud density 100 lbs./cu, ft. and above max[ surf. pressure '~ ~' :~ ~'~ 4600' 7 5/8" 33.7 P-110 L8R Requires: " · ~'%. ~ 1900 ' 7 5/8" 29.7 N-80 L8R X-over ~/~"~ ' 4070' 7 5/8" 26.4 N-80 Buttress 25 - 9 7/8" x 7 5/8" centralizers- /.~' ._~' 7 5/8" 33.7 N-80 Buttress 25 - Stop rings 7 /8" x 3 .7# P-Il0 Mod differential fill-up shoe & collar; stage co!l~ Cementing ~ s ~ ~or stage cemen~n~ ..an plugs · Liner 200' 5 1/2" 20 N-80 L8R Special clearance coupling -- 450' 5 1/2". 20 N-80 L8R Hang-er , 5 1/2" 20 LTC x 7 5/8" 33.7# P-110 Burns Plain Hanger grooved for cementings float s~c collar, plugs and centralizers. to . ·, Mesh, Rows, Slots, Centers, . HEAD: 5000 PSI CWP. Bottom Conn[ 3/4" SOW Type Top. Conn.. 10" 5000 RJ.FT-ange ,, 2-x 2" screwed Fittings 1 - screwed ~3000 psi-WOG valve, bJJll plug on ~ther side' CASING SPOOL TUBING HEAD 5000 PSI CWP. Bottom Conn. 10" 5000 PSI RJ F!anqe, type 59L Top Conn. lQ" 5000 psi ", Type Suspension ~E~ivalent to Shaffer 59L 3 1/2" Buttress up and do-vzn full bore, ' bored for 3 1/2" Casasco plug. " - · __TUBING Feet APl Size Weight Grade Threads ~, Type Remarks · (Cross-overs, etC.) Bottom 750' .' 2 3/8" 4.7 N-80 8 RD EUE 2 3/8 EUE x 3 1/2" Next 10250 ' 3 1/2" 9.3 N-80 Buttress 8 - Camco MMG Mdrls W/R - 20 valves 3 - 2 3/8" Otis S nipPles, positions 2, 3,4 · ~[ota! 4 - Baker 5 1/2" FH packers 3 - 2 3/8" Brown CC Jts. 1 - 2 3/8 shear out sub 3 - Otis 2 3/,,8" XA sleeves 1-2 3/8" Camco "D" Nipple 100' - Baker 2 3/8" Blast Tubing Catcher ~ type. Csg. Size " Wt. Install at Packer "x " Type with' "stroke at with # wt. Other Fittings XMAS TREE ~ "~ Arm PSI CWP. Dwg. No...A~-c'-'! 7A-O ~ AP-C-ITS-0 Tul~ing Beans " Type " Header " Arm PSI CWP. Dwg. No ..... Stuffing Box " :Type. Polished Ro~ "x ' Lc j ;\VVK~J v ,..,..'_ ; PUMP: "X ' ~, ~,~..~.~..P A ;;Al y pe RODS: Grade__,~ of "; ___ of .... ; ..... i 'of PUMPING UNIT. APl Size Type · Max. Stroke ' ! "Set at - ! "Stroke and Engine Motor HP Rem, ks .___.____~ --- ~ Prcparc(I By Area Supervisor Sr. Brig. Engineer~ ~ [~ ~ AppruwM t)y ~,,l.,~x = BAD Brig. Supt. j. 2000 · 5000 · 60OO ?000 8000 9000 · I1000 'COMPT~NY-'-ST^ND^P,.D OIL, r,. CO., ,0~ C,'tLZF.. PROPOSED DRILLING CURVE' .,, · · ._ · ,, ~II~:LL I~..~ SCU 24-9 · · · TIME (DAYS) · .' . ., / ,i J,, L J -1 e ! ! t. . ! · ~e ! ., 't · :'4 1' · · %., · · · i I eo I · I e i ?..:L ~ ~. i ........... I [ ~ ...... I , , - . ~ ~ _l I , __ _ I Il i il i i _ _~1 , -'~- /- , - ' ............ ~ ~ 3 FL~,?~ ..... ~ ....................... ~ ..... , . . _ _. . .... , ......... _ - , ~ ~ ..... ................. I~yc~ STUD 8o~rP: . ~ . ,. ~.~ , , , ., , ,, ~- . o,. , _ ,, , .. . sc~[~'~ _ .- - o~Pzz~_ Q~'~.~:O~/P~ .................................... : ......... : ....... ,,, ... . ~ _ , ~ . , ~ ........ - S ' CHECK LIST 'FOR NEW WELL PERMITS Company ~>~<2:J -/ " Yes No -R'~m-a~ks .............. 1. Is the permit fee attached ................... , .... /~ ..... Lease & Well 'No.. 2. Is well to be located in a defined pool ............... ~J,~z 3. Is a registered survey plat attached ................ - . ,~J~L 4. Is well located proper distance from property line ......... -~ , 5. Is well located proper distance from other wells 6. Is sufficient unded.icated acreage available in this pool ...... ?.:,~,.. 7. '-~ well to be deviated 8. Is operator the only affected party 9. Can permit be approved before ten-day wait lO. Does operator have a bond in force l l. Is a conservation order needed . ..... - ........... ~ o 12. Is administrative approval needed 13. Is conductor string provided 14. Is enough cement used to circulate on conductor and surface .... 15. ~,lill cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons .......... 17. Wil"l surface casing protect fresh water zones ............ 18. Will all casing give adequate safety in collapse, tension.& burst 19. Does BOPE have sufficient pressure rating ............. Additional Requirements' JAL LCS JCM '" Revised 1/15/75 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. 1! 333333 7777777777 !1 333333 7777777~77 1111 ]J 33 77 1111 33 33 77 li ~3 77 11 33 77 11 33 77 11 33 77 11 33 77 11 33 33 7=7 11 ~3 35 77 111111 333333 77 lllllt 333333 77 5555 5555555555 000000 55 O~ 555555 O0 O~ 55 55 55 O0 O~ 555555 000000 11 666666 222222 11 666666 222222 1111 66 22 22 1!1.1 66 22 22 I1 66 22 11 b6 22 1l ~666666~ 2~ 11 66 66 2~ 11 66 6O 22 111111 666666 2222212222 ~11111 6~b66b 2222222222 000000 000000 5555555555 O0 oo 55 00~ 0000 O0 000o 555555 O0 O0 O0 55 O0 O0 O0 55 0000 ~ : ~ 0000 O0 55 O0 O0 O0 O0 55 55 oooooo 11 1! I111 33 33333 33 33 I ~33333 lillll 333333 33 33 33 7777777777 5555555555 77777777'17 5555555555 ~ 77 55 77 55 77 555555 77 555555 77 55 77 5b 7~ 33 55 33 55 33 33 55 55 33 33 77 55 55 77 555555 77 555555 000000 '000000 00 00 00 00 00 0000 00 0000 00 00 00 O0 O0 O0 0000 O0 000o O0 O0 O0 O0 O0 000000 00000o 5555555555 5555555555 55 55 555555 555555 666666 222~22 000000 .66666 222222 000000 22 22 O0 O0 66 22 22 oo O0 66 22 O0 0000 66 22 O0 000o 66666666 22 O0 O0 O0 66{ 22 O0 O0 O0 66 2~ 0000 O0 66 6b 2~ 0000 O0 66 6b 22 O0 O0 66 66 22 0O O0 666666 2222222222 000000 666666 2222222222 o00000 '11 55 55 55 55 555555 111111 555555 ) RON~i:~G 0~. bPTO REotJEST C~EATEDI 12-SEP-,75 i6~27:47 ~ FIbE{ HDIC'iISARCUS"001[:t3750,1620~] CREATED{ 11-5~P-75 19:16:00 <157> PRINTED: t2-SEP"'15 19~16~03 B~ITCHES: /PR OW /FIbEIFORT /COPIES{3 /SPACING{i /LI~alT{407 FiLE WibL BE DELETED aFTEa PR!NTI~G SS S~ SS S$SSSS SSSSSS SS $SSSSSSS $SSSSSSS AAAAAA AAAAAA AA AA AA AA AA AA AA AA AA AA AA AA AAAAAAAAAA AAAAAAAAAA AA AA AA AA AA AA AA AA RRRRR~RR CCCCCCCC UU UU $$$SSSSS CCCCCCCC UUUUUUUUUU BB$$SSSS 000000 000000 O0 O0 O0 00 O0 0000 O0 0000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 000000 000o00 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 o000 O0 O0 O0 O0 O0 000000 000000 11 1! 11ii 111! 11 11 11 I! 11 1i 11 11 1111 II11 11 11 C*I}~PANy COu~TY lJ~50,16205 ~ATE 11-8P-75 OF S .A t~ A B A N A ,~ANOSTONE A FIELD C('}u~TY STANDARD OIL cOmPAnY OF SOLDOTNA CREE~ U~IT 24"9 AhA,SKA I)ATE 11-SP-75 L5 I.D [.N LXO I. SN LIL~ l, ILt~ LSP bGR LCAL 15 14 il 0 70 71 fi6 ? 19 18 SP BASE LINg SHIFT C~SP ARRAY AT DEPTH AT TE~P TOP DMPTH 58, bT, 47, 31, 0,1.30 0,150 OotiO0 0.~{00 0.000 0,000 0,000 0,000 lOOB, 10815, 10650, 10400° O. O. O. O. O, O, O, O, I0815, 10650, I0400, O' . ROG ARRAY DTMA ARRAY ZMN~A ARRAY TOP DMPTH 2.65 2.65 0.00 0.00 0,00 0,00 0,00 0,00 ~s.~ s~.~ o.o o,o 0.o 0. o 0.'o O~ ~ O, 000 0.000 O. 000 10630, O, O. I$S - ~ ~ 4 b b ? 8 9 10 11 ,12 13 14 15 16 i? 1~ 19 20 21 22 0 0 0 I 0 0 0 0 0 2 0 0 0 0 0 INP~JT PARAMF.~:T~R$ FROt.'~ 10t~30, TO 9712, ~I~OD XblT [~ITSZ BHT [~HTDEP 8Up'T 11,9 0,50 6,75 162, 110;21, 50, O, SPCK DSPcr. R. HDC DPji.,RGM START O, O, 2,84 0,20 1100~. 9712 ~'{¥ PHILEV {.~i~ SLIM .AK Pi{ .%.'}~ ~TOPIN PHIMAX PH~. ~, P~IDCL 200 0 000 10 0,30 62500 ~,0 2 0 O, 0,2 0 0'420 0,110 PHiNsO RTP~ PUN OAX {)Abl~ ~AOA DASH D~SD DTSH CP P~SH 0,2~0 126, ,029 78, 52, 3'7, 92, i50 180 I) L I M 0.21 Rh,IM (~RGI~ VARMC CONST ROP VAi~LI{~ CSF ~ o 1ooo.o o o? o~ o.~o~ o,~o o'bo START 10,)30, O, o, 0 STOP 9712, O, O, O' RESISTI¥ITY sTATISTICS UV~ ENTIRE INTERVAL SONIC STATI,STICS OVER ENTIR~,j iNTERVAL (;AM~:iARAY N{)T USEU IN C(]RR~;CT.ION OF DOUBTFUL POROS TY DATA ANALYSIS BY OUASIP MODEL GR. NOT USED IN 5tiALINESS DETERHINATIO~ SONIC COEFF, FRO~ STATISTIC5 WASA~p ROUTI~E U6~;D M !) POR08I TY % 973t.0 0.0 0.0 9732.0 0.0 0,0 9761.,0 0.2 11.3 I0o 9762.0 0.8 1],5 100 9763,0 1 14,2 100 9764,0 0.8 13.3 100 9765.0 0.5 12.6 100 9766.0 0,0 6,5 100 9768.0 0.0 0.0 9807.0 0.0 0,0 100 9808.0 0.0 0,0 I00 9809.0 0.0 0,0 I00 9821.0 0.0 0,0 9844.0 0.4 12.2 100 9849.0 0.0 0,0 9850.0 0.0 0,0 9860,0 0,3 11,8 I00 9861,0 0°8 13,5 I00 9862,0 0.3 ll,h 100 9863.0 2 15,2 8~ 9864,0 O.q i. 3,8 100 9865.0 6 17.9 98 9866.0 7 18,1 100 9875,0 0.0 0.0 9876,0 0.0 0,0 9877.0 0.0 0,0 9916,0 0,0 8,7 100 9917,0 0,4 8,2 60 9918,0 0,0 1,4 100 9919,0 0,0 0,0 I00 9923 9924 9925 9926 9927 9928 9929 .0 .0 ,0 · 0 ,0 .0 ,0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0 0 0,00 41 57 55 68 37 57 38 57 02 b8 49 56 0 0'00 0~00 46 56'66 18'68: 0 0,00 0,00 o 0 o0 · 0 0,00 0.00 38 50 55,04 i 0 0 · O0 0, O0 0 0,00 0.00 0 0 0,00 0.00 0 DEPTH FEET 9930,0 9952.0 9953,0 9954,0 9985.0 9986,0 9987,0 9988.0 10034.0 lOOJ5.O lOOJ6.O 10037.0 10038,0 I00~9.0 10040,0 10044.0 10045,0 10046.0 1U047.0 i0049.0 10050,0 i0051.0 10065.0 10066.0 10067,0 10068.0 10069.0 10070.0 lO0?1,0 10072.0 10073,0 10074.0 10092.0 I0093.0 i0094,0 10099.0 10100,0 10116o0 10117,0 PER~. MI) 0.0 0.0 0.0 0.0 0,0 0,0 0o0 0.0 0,0 0,0 0,0 0,0 0.0 0.0 4OO 2OO ,~00 0.0 0.0 0,0 0,0 O, 0 0.0 0.0 0.4 10 50 40 20 70 lO0 0,0 0,3 0.1 0.0 0,2 0.0 0,0 POROSITY 0,0 0°0 0,0 0,0 0,0 0.0 0,0 0.0 7.0 7.1 7.2 4°3 28.4 29.2 0,0 0,0 0,0 ?°9 20.1 23,6 22,1 20.0 23.9 26,9 6.2 11,6 I0,1 7.1 11.1 6,1 6.2 i~ATEit % 100 1 O0 100 100 lO0 100 ! O0 100 100 100 100 I00 100 100 lOO I00 I00 100 I00 100 100 100 i00 I00 iOU I00 100 I00 o o.oo o.oo o oo o O 0,00 48 54.~9 43 54 4,5 44 47 48 !8 41 18 54,35 54.29 0 54,13 0 5 44 0 0,00 0,00 { o o;oO o;oo } 0 0, O0 O, O0 40 52,74 18.63 22 0 0 2 51,63 18.6~ 5O 5 18 63 FEET 10118.0 10119°0 I0120.0 I0121.0 10122.0 10123.0 10128.0 lO12g. O lOJ30.O 10132.0 I0135.0 10136,0 10137.0 10142.0 10146.0 10147.0 10148.0 10150.0 10156.0 10159.0 10160.0 10161.0 10162.0 10163.0 10164.0 10171.0 10179.0 10182.0 10222,0 10223.0 I0230,0 10231,0 I0232,0 PERM. ~D O. 0 0.0 0.0 0o0 0.0 0.0 0°0 0°0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0o0 0 0 0.0 0.0 0.0 0 o 0 0.0 0.0 0.o 0°0 0°0 0.0 0.0 0.0 0.0 O° o 0.0 POROSITY % 7,1 7,8 6,5 6,8 7.5 5,0 5,7 5.0 4,7 3,5 o,1 5,7 3.1 4.0 2.5 ].9 4.7 5,2 5,9 3,7 1.4 4.3 4,3 5.5 ?,2 5.5 0.0 0.0 0.0 S~%T, % i00 IO0 I00 100 IO0 100 1o0 lO0 io0 lou I00 100 I00 1o0 100 I00 100 100 1oo I00 10o I00 IO0 10o 100 lOO 10o I00 100 4 1 { 48 ~0 47 49.89 18,63 47 48 4~ 49,22 i8,63 4B 49,14 48 49,01 41 48,85 ]7 45 48.76 46 47 48,53 i~.63 48,44 18,63 49 48.21 i8,63 4j 47 o o,oo o'oo : 0 0.00 0.00 0 DEPTH FEET POROSITY % SAT. HYCA~B 10~41.0 10242,0 10243.0 10333,0 10334,0 10335,0 10357.0 10398.0 10359,0 10360.0 10362,0 10363,0 10364,0 10379,0 10380,0 10381,0 10389.0 10392,0 I0393.0 10395,0 1039b,0 10398,0 10399,0 10400,0 10401,,0 10402,.0 10405,0 {,0406.0 10425,0 10426,0 10428,0 I0429.0 {,0455,0 10456,0 1045'7.0 0,0 0..0 0,0 0.o 0,0 0,0 0.0 0.0 0,0 0.0 0.1 0,1 0.0 0.0 0,0 0,0 0o0 0.0 0,0 Ow, 0.0 0.0 0,0 0,0 0,0 0.0 0.0 0,1 0,0 0.0 0.1 0.0 0.1 0.! 0,0 0.0 0,0 6,5 5.5 6,4 9.2 9.1 6,4 0.0 0.0 7.7 7.4 7.7 5.5 5.5 4,5, 7,0 t~,1 5.2 9.2 ~.5 9.3 6.7 10.1 10,0 100 100 100 100 100 I00 i00 10~ 100 100 100 100 100 100 100 100 100 100 I00 100 100 1o0 100 100 lO0 100 100 I00 100 I00 5 35 47 63 49 49 46.9t 1S,63 28 46,72 !8,03 47 46 44 45 45 18 63 49 45 63 35 44 8 FEET 10458.0 I0459.0 I0461,0 10462.0 10473.0 10474.0 10475.0 10476.O 10477.0 10478.0 10479.0 10480.0 i0481,0 10482,0 10483.0 104B4.0 10485,0 10486.0 10487.0 10488.0 10489.0 10490,0 1049J..0 10492.0 10493,0 10494,0 10495,0 10496,0 10497,0 10498,0 10499,0 10500,0 10502.0 10503,0 10504,0 10505.0 10506.0 10507°O 10508,0 10527,0 10528.0 10529,0 10530.0 10538.0 PERM, M [) 0,1 0.1 0.0 0.0 0°6 1 2 2 1 0,5 0,5 0,2 0,0 3 0,5 0,5 0,0 0,8 0,9 2 0,1 o,o 0,3 0,4 0.0 0,0 0.0 0.0 0.0 O. 0 0°0 0.0 0,0 0o0 P()Rt)S ITY % 9,0 9,! 0,0 0,0 12,9 14,0 15,3 14,4 12,5 12.5 10.7 15.9 15,0 12.5 14.? 14,9 14,4 12,7 13,b 13,8 14.7 14,8 14,8 10.4 li.9 15,0 12,! 0.0 0,0 0,0 0.0 0.0 0°0 0,0 9,2 9,7 8,0 6.7 ~AT~R SAT ° % I00 100 lo0 100 100 99 97 98 lo0 I00 100 100 88 9~ 76 ?8 73 93 I0~ 80 100 100 100 100 loo 100 10o 100 40 44,78 0 0,00- 0 0 0,0 0 O0 33 44,52 18 ~3 29 44~38 i8 *~ 29 44,24 18,63 30 43,93 18 6~ 39 43,64 18,62 30 43,40 18,6~ 39 32 42,~i i8,52 ]9 42.32 18o45 33 41,84 18,38 0 0.00 0°00 0 ~00, .:' 0 0.00 0,00 t9 40,55 i8,26 42 48 40.38 18,26 40 40.i4 18,2b ~ DEPTH FEET PER~, ~D % HATER 10539,0 10540,0 10541,0 10542,0 10545°0 10546,0 I0559,0 10563,0 10564,0 10565.0 10566.0 10567.0 10568,0 105bV,O 10570.0 1057],0 10574,0 10575,0 10576,0 10577,0 10578.0 10579.0 10580,0 10581,0 10582,{) 10583.0 10584.o 10585,0 10586,0 I0587,0 10588,0 10589,0 10590,0 10591,0 I0603,0 10604,0 10609,0 10610,0 10611.0 10612,0 10613.0 10614,0 0,0 0,0 0,0 0o0 Oeo 0°0 0.1 0.5 0.3 0.~ 0,0 0.7 O,g 0,, ! 0,8 0,? 1 0,6 0.3 0.2 0,0 0.0 0.0 0,0 0,0 0,0 0.1 O.q 5 q 7 q 7,1 6,7 4.a 0o0 13,7 I1,7 10,9 I1,8 6,5 12.7 13,0 13.4 13.1 13.9 14,4 15.2 14.7 13,2 13.1 14,7 14,3 12.5 11.~ 10.3 8,1 6,4 4.9 13.2 17,9 18,5 100 lO0 I00 lOo 100 100 1 O0 100 100 77 72 80 9I 95 I00 loO 10o IO0 1 oo 100 1o0 100 99 100 97 98 8'7 70 100 100 100 10o lo0 100 100 100 48 40 ~0'~ 47 40,01 4b 4 .8V~4 44 39,72 43 39.65 47 32 · 33 39.18 33 38,92 18 39 38,6g 18 49 38, 31 38.43 29 3a,3o ~ 30 -38,16 29 38,03 18,15 27 2B 32 27 22 37 b 37,46 18,i5 37,i~ i8 36~76 36,64 41 36,,29 43 ~6.05 18'07 39 36,00 i8,07 -/ · 41 $5,9i 21 35,66 20 DEPT~ FEET 10615,0 10616,0 10617.0 1O618°O 10619,0 106~1,0 10622.0 10623.0 10624.0 10625,0 10 0,2 0,0 0,0 o,0 0,0 0o0 POI.! 0;5 % 17,2 12,,4 10,0 7,0 0,,0 0,0 0,0 0,0 97 8~ 9~ 77 lot) 0 0 0 0 18 J4 94 ~4 1 { 50 J4,09 i7 ~)5 ~ 1 0 ~ 0.o0 0'o0 ~: ~ 0 0,0~ 0,00 o o~oO %o~ ~ : ~ I 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 INPUT PARA~,~KTE~'6 FRU~ 11008, 'i~O 10630, O. 2,84 0,2o 1100~, 9712, 0,000 l,O0 0,000 ,]0 20,00 .200 0,000 .10 0.30 62b00. t~.O 2°0 lob30. 0,240 0 0,2RO 12b, ,029 92, 150, 15 190 0.O0 0°4] 0,21 4,0 1000,0 0.07 STATISTICS 5P START I 1008, O, O, 0. STOp lObgO, O, O. START 11000. O. O. O, STOP 10030, O. O. O. SONIC STATISTIC~ OVE~ ENTIRE GAI~tI"tARA¥ NOT USED IN COt~R~;CTION OF ANAI,¥~IS BY oUA$IP ~ODEL PERHEABILITY BY TInUR EOUAT~ON SP COFFF. FR{}~ STATIST GR COEFF, FRO~ STATISTICS 5~IC COP'fFF, F¢O~ ST~T ~ASA~p ROUTINE USED Oo O, O, O. O- DEPTH PERM, DORO$IT¥ FEET MD % 5AT. % 10633,0 0,0 ~.1 lOO 10655,0 0,0 0.0 10656,0 0,0 0.0 106bl,O 2 10,9 10662,0 5 1066],0 10 13,6 106b4,0 20 14.4 10665,0 20 15,1 I0666,0 20 t4,3 10667,0 10 14,0 I0668,0 20 15.1 10669,0 40 16,1 10670,0 40 15,5 10671,0 30 15,1 I0672.0 40 15,3 I0673,0 20 14,1 10674,0 20 13,8 I0675.0 ]0 14,4 10676,0 20 14,2 I0677,0 20 13,7 1067fl.0 I0 13,7 10679,0 9 12,7 10680,0 8 i2,6 10681,0 6 11.8 10682,0 4 11,0 10683,0 ? i2,0 10684.0 4 11,0 10685,0 2 10,0 10686,0 0.~ 10697,0 0,0 10698,0 2 1 10699.0 5 10700.0 5 1 10701,0 5 1 10702,0 4 1070~,0 2 1 10704,0 3 1 10705,0 5 1 10706,0 6 1 10707,0 7 1 10708,0 6 I I0709,0 3 10710,0 0,2 10711,0 0,0 7,4 0,4 1,9 1,5 !,7 1,4 0,5 0,7 1,O 2,5 6,2 5l 42 3b 31 30 30 30 27 25 24 24 25 25 25 29 30 33 33 33 35 44 39 38 40 4O 37 3~ 34 33 34 41 i00 10713.0 0,2 6.0 42 47 33,94 0 O, o o, o~ 0,4 31 0,4 25 0.4 26 32,90 i7,52 ' 32,62 i7,32 0,4 27 32.30 17,09 0,4 ~8 ' 9,~ 0,4 29 32.00 i6,,86 0,4 c 32. 0,3 33 31.7! 16,64 o,~ 33 31,57 ~ 0,2 0,5 36 31,42 16,43 37 38 30,89 16.05 39 30,65 15,89 !5,74 47 30.21 15,hI 5O 39 29,84 4i 29:*72 38 29,61 38 .49 15,47 15,32 ]9 29.1'? i5,05 37 ~? 30 28,68 14,7~ 37 28,54 14,65 qb 28.51 14,~,5 DEP H FEET 10715.0 1071b.O 10717,0 10718.0 10719.0 10720.0 10721,0 10722.0 10723.0 10724.0 10725.0 10726.0 10727.0 10728.0 I0729.0 107~0.0 10731.0 10732.0 10733.0 10734.0 10735.0 I07j6.0 10737.0 10738.0 10743.0 10744.0 10745.0 !0746.0 t07q7.o 10748.0 10749.0 10750.0 10751.0 10752.0 10753.0 10754.0 10755,0 10756.0 10757,0 10758.0 I0759.0 I07~0.0 10761,0 10762,0 10763.0 10764.0 MD 10 2O 10 iO 10 4 10 20 20 4 4 0.3 O. 0 0.0 0.o 0.0 3 10 20 I0 2o 30 2O 20 20 10 lO 10 10 10 2O 20 POROalTY % 10.5 11.2 11.0 12.3 13.3 14.2 14.0 13.5 13.6 12.7 li." 10,9 lb.1 15.0 13.1 li.O 11.7 13,7 0,0 10.5 11.9 1t.2 13.3 13.0 12.9 15.2 14.7 14,i 15.4 15.7 15.1 14.7 14.i 1~,7 13.3 13.~ 12,7 12.8 14.1 14.5 32 31 31 33 34 31 29 31 31 41 41 39 43 I00 100 98 70 49 45 34 32 30 30 30 30 31 30 30 31 29 27 27 0.6 O. O. 0.6 0.8* 39 43 40 3~ 4O 42 34 7 27 17 13 ~6 94 13 ¸65 47 75 34 19 O5 0.5 0.4 0.4 21 0.4 21 0.4 20 23.15 0.2 0,3 FEE'{' PERM. M D % 5AT , % H¥CARB 107b5,0 10766,0 10767.0 10768,0 10769,0 10770.0 I0771,0 10772°0 10773.0 10774,0 10775.0 10776.0 10777.0 10778o0 I0779.0 IO?BO,O 10781.0 10782,0 10783.0 10784.0 10785.0 I0786.0 I0787,0 10789.0 10790,0 10791.0 10792,0 10793.0 10794.0 10795.0 10796,0 I0797,0 I0798.0 10799.0 10800.0 i0801.0 10802.0 10826,0 10827.0 10828,0 10829.0 10830,0 10831.0 10832,0 10833.0 10834,0 2O 20 20 10 I0 10 10 2o 30 20 0.2 0.0 0,0 0,0 20 20 0.0 0.0 t 1 2 0.0 0,0 0,0 0.0 0.5 0,0 0.0 0.0 4 7 9 I0 20 2 0.8 14,3 14,1 14.0 13,b 13,0 15,2 15.6 14.4 12.2 lO.1 2,0 14.3 10,2 1,7 0,0 I0,4 10,1 7.4 8.9 9,7 10,5 0,0 0,0 0,0 i,2 7,5 5,7 12,2 13.4 13,9 14.9 15,3 12,1 10.6 9,4 2~ 29 31 32 3i 29 31 5b 31 2~ 27 100 100 47 5~ 57 50 4~ 0 0 0 ~00 60 100 ~00 44 41 40 5,4 0.3 22 22 .0 I0 BI O.4 25 22 0,4 24 22,32 lO,bl 0.4 24 22~i8 0,4 0'4 O,q 2~ 21,51 10,05 0,4 0.4 23 o.3 0,3 24 31 47 20,22 9,22 41 44 !9,95 9,10 19,78 9,03 0,00 0.,00 0 0,00 0,00 47 19,60 B-~94 47 1g,54 8.90 49 46 19,39 8,89 ~9 19,0i 35 18,88 8,79 31 18,61 8.b2 37 18,31 8,43 44 18,07 8,29 4~ DEPTH FEET ~D % ~ATEt~ H~CAR!~ DRO,S T¥ 10835,o 6 1],0 42 10836,0 5 12.3 10837,0 0,7 10838,0 0,0 3.8 94 10839,0 0o0 0.0 100 i0840,0 0.0 0.6 100 10841,0 0,0 0,7 100 10842,0 0,0 2,6 100 I0843,0 0.2 10844,0 q 10845,0 20 16,2 34 10846,0 40 18,2 34 10847,0 30 16,7 32 10848,0 30 16.4 33 10849,0 10 10850,0 10 14.5 40 10851,0 20 15.8 37 10852,0 10 14,b 39 10853,0 10 14,3 40 10854,0 5 12,6 40 I0855,0 3 11,5 44 10856,0 4 12.1 44 10857,0 q 14.2 42 10858,0 8 14,1 43 10859,0 10 15,0 42 10860,0 10 i5,0 41 10861.0 10 14.9 42 10862,0 7 14,1 45 10863,0 10 14,8 42 10864,0 9 14.5 43 10865,0 5 12,8 42 10866,0 10 14,2 39 10867,0 30 17.5 34 10868,0 30 16.6 I0869,0 30 17.1 34 10870,0 30 16,8 54 10871,0 30 16,4 33 10872,0 ]o 16,9 10873,0 40 l~.l 34 10874,0 30 17,0 35 10875,0 30 17.3 37 10876,0 30 17,7 37 10877,0 20 17.0 37 10878.0 30 17.6 10879.0 20 i6,5 39 10880,0 ]0 17.1 37 10881,0 20 1~,6 37 10882.0 30 17.0 37 37 33 87 ~ 9 17 47 8 { 27 16 7 65 { 26 16 27 16,58 7,43 30 14,89 O,b 29 14,60 6,27 0.~ o,8~ 0,8, 20 13,69 5,70 0,8, 0,8+ 0,8. 13 01 5 25 0,8, 23 12,66 5,02 20 12,31 4,80 0,8~ 25 11,96 4,59 27 I 63 4 38 0,8~ OEPTH FEET POROSITY % ~ATER HYCARB 10804,0 10885,0 10886,0 10887,0 108fl8,0 10889,0 10~90,0 10091.0 10892,0 10893,0 10894°0 1089S,0 10896,0 10897,0 10898,0 10899.0 10900,0 10901,0 10902,0 10903,0 10904.0 10905,0 i0906,0 ioq07,O 10908.0 10909.0 10910,0 10911,0 10012,0 i0913,0 10914.0 !0915.0 10916.0 10917.0 10918,0 10919,0 10920.0 10921.0 10922,0 10923.0 10924.0 10925.0 1092b.0 10927.0 10928.0 10929.0 10930.0 30 20 10 6 2 0.7 0.0 0.3 0.1 3 5 7 4 10 3 7 q 10 2O 7 2 2 4 2 4 7 3 2 5 3 0.5 7,0 6.4 4,7 2,9 1,5 9,6 0,5 1,1 2,8 9,5 1.6 3,4 4,1 4,5 4.8 3,5 5,5 3,7 4,1 6,3 1,9 1,6 1,4 1,7 5,6 4,0 3,2 1,4 1,4 37 40 72 I00 59 5b 5i b3 50 4b 43 42 48 44 43 4~ 5b 59 56 54 90 49 53 .~0 54 o,s, 2 3.1 40 !1 29 4 1 96 3 95 40 10.26 Itl 9,79 .].5~ i 35 9 2 .2' 37 8.93 3.11 ..8I 0,7 O--b 3~ 8.42 2,84 29 8.t4 2,69 ~0 ~ ~ 29 7.82 2.51 29 32 7.31 2.27 37 7.07 2.I6 40 36 6.B4 32 6.54 1.91 37 6,26 1.77 33 6,01 l,b5 35 32 5,7b i,54 29 5.4~ 1.40 32 5.21 1.29 DEPTM FEET I0931,0 10933.0 10934.0 I0935,0 10936.0 10937,0 10939,0 10940.0 10941.0 10942.0 10943°0 10944.0 10945,0 10946,0 10947,0 10948.0 10949,0 10950,0 I0951.0 10q52,0 1095~,0 10954.0 10955,0 10956.0 10957.0 10959,0 10960,0 10905,0 I0984,0 10985,0 10986.0 109B7,0 I0988.0 10989,0 10990,0 10991.0 10992.0 10993,0 10994.0 10995,0 10996,0 10997,0 10998.0 PERM. 0,3 O. ! 0,0 0.0 0.0 0.0 0.0 0,0 0.0 0,0 0,0 0,0 0,5 0o 3 0,! 3 0,4 0.4 O, 2 0.3 0.0 0,,0 0.0 0.0 0.1 0,2 0,0 0.0 0,0 0..0 0,0 0o0 0ol 0..4 0.3 2 0.1 PONOMITY % 1,7 0,8 3,1 3,2 3.6 0.3 0,0 0,0 0.0 0,0 0,0 3,0 7,8 t.9 1,0 3,,1 1,,4 0.5 2, '1 5.2 ] .9 2,~ H,1 0.0 0.0 0.0 7.9 9.0 9.9 8.1 5.3 3,8 6.6 9.4 11.6 10.9 12,8 12.1 9.1 7O 71 55 51 '; l 100 IO0 I00 I00 100 100 100 73 97 I00 (59 7O 94 100 lo0 71 100 1o0 100 100 100 lO0 76 ~5 100 DENS, VObUME P£)RO~ITY ~Y( RB ~ GM/CC 2b 32 76 4 14 4,38 1,01 42 43 42 0 94 34 3,i7 0,69 46 O0 o :: %00 49 39 41 32 23 10999,0 11000.0 11001.0 11o02°O 11003,0 11004,0 11005,0 ilO06,0 11007,0 ilO08,0 0,4 1 1 2 2 I O,q % 3.2 4,9 4,1 4,5 % 71 70 7I 76 72 bi HYCARB C-bAY' CU-){., VOk, iJ~E POROSITY HYC
