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Home My WebLink About160-0191.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 Plunger Lift 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): 11,119'10,409 (fill) Casing Collapse Structural Conductor Surface 1,130 psi Intermediate 3,090 psi Production 6,390 psi 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: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 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 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: August 20, 2020 2-3/8" 11,119' Perforation Depth MD (ft): 4,120' See Attached Schematic 11,119'10,932'5-1/2" 15'22" 13-3/8" 9-5/8"4,120' 1,469'2,730 psi1,469' 4,119' 1,469' 15'15' 4.6# / L-80 TVD Burst 10,305' 7,740 psi MD 5,750 psi Length Size CO 123A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028997 160-019 50-133-10107-00-00 Soldotna Creek Unit (SCU) 332-04 Swanson River Field / Hemlock Oil & G-Zone COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic tkramer@hilcorp.com 10,932'10,409'10,246'1,200 10,502' Baker HP1-AH; N/A 10,285' MD/10,125'TVD; N/A; N/A Perforation Depth TVD (ft):Tubing Size: m n P 66 t er Lr LLLLLLLLLLLLLLLLLLift Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:09 am, Aug 06, 2020 320-322 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.06 07:53:14 -08'00' Taylor Wellman X * Witnessed Pressure test of surface Plunger equipment to 2000 psi DLB 08/06/2020 gls 8/25/20 10-404 DSR-8/6/2020Comm 8/25/2020 dts 8/25/2020 JLC 8/25/2020 RBDMS HEW 8/26/2020 Well Prognosis Well: SCU 332-04 Date: 8/5/2020 Well Name: SCU 332-04 API Number: 50-133-10107-00 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: August 20th, 2020 Rig: N/A Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-019 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Second Call Engineer: Ryan Rupert (907) 777-8503 (O) (907) 301-1736 (M) AFE Number: Current Bottom Hole Pressure: ~ 1,200 psi @ 10,234’ TVD (Based on pressure survey ran in well on 4/29/13 at 10,400’ MD.) Maximum Expected BHP: ~ 1,200 psi @ 10,234’ TVD (Estimate based on offset wells in the on 4/29/13 at 10,400’ MD.) Max. Potential Surface Pressure: ~ 1,098 psi (Based on actual reservoir conditions Minus 0.1 psi/ft) Brief Well Summary Swanson River Unit 332-04 (originally permitted as SRU 32-04) was drilled as a grassroots in 1960. The well was converted to gas injection in 1967. The Hemlock intervals were isolated with a PX plug and the well recompleted in the Tyonek G in 1996. The Tyonek G has been re-perforated several times, including 2000, 2003, 2004, 2005, and 2009. This work covered by this Sundry is to install a plunger lift system to the current well. Notes Regarding Wellbore Condition x The last fill tag depth showed fill close to the bottom of the perforated interval at 10,421’ SLM. x Tree connection is 2.5” Bowen. OBJECTIVE OF Wellwork Purpose of this Sundry is to install a gas lift assisted plunger lift. Slickline Procedure: 1. MIRU s-line unit. Pressure Test lubricator to 2,000 psi Hi 250 Low. 2. PU and RIH with GR to determine largest that can pass to stop set depth. 3. PU RIH W/ F-stop to 10,100’. Note: Take care to stay on top of wire fish (TOF @ 10,273’). 4. Set stop and Pooh to PU Bumper stop and standing valve. RIH and set on top of F-stop @ +/- 10,096’. POOH. RDMO slickline. 5. Install plunger catcher on top of tree. 6. Wire in controller. 7. Install Plunger and drop same the cycle. Note: No piping changes are required to install this system. 8. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Wellhead drawing SSV is in vertical run. Note: No piping changes are required to install this system. SCU 332-04 Schematic 05-18-18 Updated by DMA 05-18-18 Soldotna Creek Unit SCU 332-04 Soldotna Creek Unit Well SCU 332-04 As Completed 10/4/96 Last Updated 10/10/14 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 18.59’ 0.58’ 1.995” Tubing Hanger w/ CIW type H BPV 2 6.25’ (+/-) 1.901” 4.25” GLM @ 2,059’, 3,124’, 4,113’ 5,093’, 6,048’, 6,760’, 7,473’, 8,127’, 8,778’, 9,428’, 10,113’ 2A 7,516’ DV Collar 3 10,284’ .85’ 2.50” 3.75” Baker K Anchor 4 10,285’ 7.22’ 2.390” 4.375” Baker HP1-AH Packer 5 10,299’ .73’ 1.875” 2.875” X-Nipple 6 10,305’ .67’ 1.995” 2.875” Wireline Re-entry 7 10,453’ 4.475’ 2.688” 4.57” Baker SC-2P Packer 8 10,457’ 5.53’ 2.995” 3.50” Baker Millout Extension 9 10,476’ 4.04’ 1.875” 3.10” Sliding Sleeve CMU 10 10,502’ .75’ 1.875” 3.10” X-Nipple (PX Plug set in same on 9/19/96) 11 10,510 3.98’ 1.995” 4.125” Baker Telescoping Joint 12 10,515’ 2.82’ 2.441” 2.90” Bowen 150 Overshot w/ Grapple 13 10,530’ 3.92’ 3.10” Brown HS-16-1 Packer 14 10,600’ 13.07’ 2-3/8” Camco MM GLM 15 10,643’ 3.92’ Brown HS-16-1 Packer 16 10,662’ 1.47’ Otis S Nipple Position 1 17 10,723’ 13.0’ 2-3/8” Camco MM GLM 18 10,766’ .89’ Camco D Nipple 19 10,768’ Baker Model F Packer 20 10,833’ Tubing Tail with Muleshoe Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural Surface 15’ cemented 13-3/8” Surface 54.5#, J-55 Surface 1,469’ 8rd STC / 12.615” 1,100 sxs cement 9-5/8” Intermediate 43.5#, N-80 Surface 186’ 8rd LTC / 8.755” 350 sxs cement 47#, N-80 186’ 3,661’ 8rd LTC / 8.681” 40#, N-80 3,661’ 4,120’ 8rd LTC / 8.835” 5-1/2” Production 23#, N-80 Surface 1,667’ 8rd LTC / 4.670” 600 sxs cement (1st stage) 500 sxs cement (2nd stage) 20#, N-80 1,667’ 3,897’ 8rd LTC / 4.778” 17#, N-80 3,897’ 6,964’ 8rd LTC / 4.892” 20#, N-80 6,964’ 9,459’ 8rd LTC / 4.778” 23#, N-80 9,459’ 11,119’ 8rd LTC / 4.670” Tubing 2-3/8” Production 4.6#, N-80 Surface 10,306’ Butt / 1.995” 2-3/8” Production 4.6#, N-80 10,452’ 10,515’ Butt / 1.995” 2-3/8” Production 4.7#, N-80 10,515 10,833’ EUE 8rd / 1.995” Perforation Data ZONE TOP BTM Shot Condition G-2 10,388’ 10,423’ 6spf Perf 8/18/96 [Reperf 10/3/96, 12/13/00, 3/10/02, 3/05/03, 11/13/03, 11/28/04, 5/01/05, 2/28/09, 2/08/14] Hemlock 10,450’ 10,450’ Isolated by PX plug - Active 10,470’ 10,495’ Isolated by PX plug - Active 10,509’ 10,525’ Isolated by PX plug - Active 10,542’ 10,630’ Isolated by PX plug - Active 10,655’ 10,713’ Isolated by PX plug - Active 10,721’ 10,764’ Isolated by PX plug - Active 10,779’ 10,825’ Isolated by PX plug - Active 10,833’ 10,875’ Isolated by PX plug - Active Pro # 2 2 3 4 5 6 7 8 9 1 1 1 1 1 1 1 1 1 1 2 Cas Si 2 13- 9-5 5-1 Tub 2-3 2-3 2-3 Perfo ZON G- Heml Fish Detail: Top Fish – Approx 116’ of .125 SL wire, 23’ tool string, wire grab. 5’ wt. bar, rope socket, wire grab, wire finder, 5’ wt. bar, rope socket per 11/20/16 WSR. See Drawing. Bottom Fish –Temp Sub & Spinner Tagged @ 10,708’ on 9/14/87. PTD: 160-019 API: 50-133-10107-00 Lease: FEDA-028997 Spud Date: 3/30/1960 Tree cxn: 2.5” Bowen Lift Threads (Short String): 2-3/8” IBT Lift Threads (Long String): 2-3/8” IBT Well Data Updated by DMA 08-05-20 SCU 332-04 PROPOSED SCHEMATIC Soldotna Creek Unit Well SCU 332-04 As Completed 10/4/96 Last Updated 10/10/14 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 18.59’ 0.58’ 1.995” Tubing Hanger w/ CIW type H BPV 2 6.25’ (+/-) 1.901” 4.25” GLM @ 2,059’, 3,124’, 4,113’ 5,093’, 6,048’, 6,760’, 7,473’, 8,127’, 8,778’, 9,428’, 10,113’ 2A 7,516’ DV Collar 2B 10,096 Bumper Spring & F Stop 3 10,284’ .85’ 2.50” 3.75” Baker K Anchor 4 10,285’ 7.22’ 2.390” 4.375” Baker HP1-AH Packer 5 10,299’ .73’ 1.875” 2.875” X-Nipple 6 10,305’ .67’ 1.995” 2.875” Wireline Re-entry 7 10,453’ 4.475’ 2.688” 4.57” Baker SC-2P Packer 8 10,457’ 5.53’ 2.995” 3.50” Baker Millout Extension 9 10,476’ 4.04’ 1.875” 3.10” Sliding Sleeve CMU 10 10,502’ .75’ 1.875” 3.10” X-Nipple (PX Plug set in same on 9/19/96) 11 10,510 3.98’ 1.995” 4.125” Baker Telescoping Joint 12 10,515’ 2.82’ 2.441” 2.90” Bowen 150 Overshot w/ Grapple 13 10,530’ 3.92’ 3.10” Brown HS-16-1 Packer 14 10,600’ 13.07’ 2-3/8” Camco MM GLM 15 10,643’ 3.92’ Brown HS-16-1 Packer 16 10,662’ 1.47’ Otis S Nipple Position 1 17 10,723’ 13.0’ 2-3/8” Camco MM GLM 18 10,766’ .89’ Camco D Nipple 19 10,768’ Baker Model F Packer 20 10,833’ Tubing Tail with Muleshoe Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural Surface 15’ cemented 13-3/8” Surface 54.5#, J-55 Surface 1,469’ 8rd STC / 12.615” 1,100 sxs cement 9-5/8” Intermediate 43.5#, N-80 Surface 186’ 8rd LTC / 8.755” 350 sxs cement 47#, N-80 186’ 3,661’ 8rd LTC / 8.681” 40#, N-80 3,661’ 4,120’ 8rd LTC / 8.835” 5-1/2” Production 23#, N-80 Surface 1,667’ 8rd LTC / 4.670” 600 sxs cement (1st stage) 500 sxs cement (2nd stage) 20#, N-80 1,667’ 3,897’ 8rd LTC / 4.778” 17#, N-80 3,897’ 6,964’ 8rd LTC / 4.892” 20#, N-80 6,964’ 9,459’ 8rd LTC / 4.778” 23#, N-80 9,459’ 11,119’ 8rd LTC / 4.670” Tubing 2-3/8” Production 4.6#, N-80 Surface 10,306’ Butt / 1.995” 2-3/8” Production 4.6#, N-80 10,452’ 10,515’ Butt / 1.995” 2-3/8” Production 4.7#, N-80 10,515 10,833’ EUE 8rd / 1.995” Perforation Data ZONE TOP BTM Shot Condition G-2 10,388’ 10,423’ 6spf Perf 8/18/96 [Reperf 10/3/96, 12/13/00, 3/10/02, 3/05/03, 11/13/03, 11/28/04, 5/01/05, 2/28/09, 2/08/14] Hemlock 10,450’ 10,450’ Isolated by PX plug - Active 10,470’ 10,495’ Isolated by PX plug - Active 10,509’ 10,525’ Isolated by PX plug - Active 10,542’ 10,630’ Isolated by PX plug - Active 10,655’ 10,713’ Isolated by PX plug - Active 10,721’ 10,764’ Isolated by PX plug - Active 10,779’ 10,825’ Isolated by PX plug - Active 10,833’ 10,875’ Isolated by PX plug - Active Pro # 2 2 2 3 4 5 6 7 8 9 1 1 1 1 1 1 1 1 1 1 2 Cas Si 2 13- 9-5 5-1 Tub 2-3 2-3 2-3 Perfo ZON G- Heml Fish Detail: Top Fish – Approx 116’ of .125 SL wire, 23’ tool string, wire grab. 5’ wt. bar, rope socket, wire grab, wire finder, 5’ wt. bar, rope socket per 11/20/16 WSR. See Drawing. Bottom Fish –Temp Sub & Spinner Tagged @ 10,708’ on 9/14/87. PTD: 160-019 API: 50-133-10107-00 Lease: FEDA-028997 Spud Date: 3/30/1960 Tree cxn: 2.5” Bowen Lift Threads (Short String): 2-3/8” IBT Lift Threads (Long String): 2-3/8” IBT Well Data open GLM SCU 332-4 Well head Drawing 1 Carlisle, Samantha J (CED) From:Ted Kramer <tkramer@hilcorp.com> Sent:Monday, August 24, 2020 2:42 PM To:Schwartz, Guy L (CED) Subject:RE: [EXTERNAL] SCU 332-4 (PTD 160-019) plunger lift. Attachments:SCU 332-04 Proposed 08-05-20.doc Follow Up Flag:Follow up Flag Status:Flagged Guy, Therearestillactivegasliftvalvesinthewell.Butgaswillprimarilybeinjectedatthebottommostmandrelat10,113’ toassisttheplungertolift.Theplungermoreorlessactslikeasealtohelpsweepthefluidupthetubing. TedKramer Sr.OperationsEngineer HilcorpͲAlaskaLLC Office–907Ͳ777Ͳ8420 Cell–985Ͳ867Ͳ0665 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Monday,August24,202010:50AM To:TedKramer<tkramer@hilcorp.com> Subject:[EXTERNAL]SCU332Ͳ4(PTD160Ͳ019)plungerlift. Ted, Asthisisaoilwellcanyouexplainhowtheplungersystemwillwork…istheIAisolatedfromtheplungersystem.?Are thereopenGasliftmandrelsabovethebumpersuborbelow… GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. 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No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 6* -:CES EID STATE OF ALASKA1 AKA OIL AND GAS CONSERVATION COI SION REPORT OF SUNDRY WELL OPERATIONS MAY 20181 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U ADOG Ctn U Performed: Suspend ❑ f s Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: e'er" ltice'k- 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: F r r44 Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 50-133-10107-00 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑ 6.API Number: AK 99503 160-019 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028997 Soldotna Creek Unit(SCU)332-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil&G-Zone 11.Present Well Condition Summary: Total Depth measured 11,119 feet Plugs measured 10,502 feet true vertical 10,932 feet Junk measured 10,708 feet Effective Depth measured 11,031 feet Packer measured 10,285 feet true vertical 10,846 feet true vertical 10,126 feet Casing Length Size MD TVD Burst Collapse Structural 15' 22" 15' 15' Conductor Surface 1,469' 13-3/8" 1,469' 1,469' 2,730 psi 1,130 psi Intermediate 4,120' 9-5/8" 4,120' 4,119' 5,750 psi 3,090 psi Production 11,119' 5-1/2" 11,119' 10,932' 7,740 psi 6,390 psi Liner Perforation depth Measured depth See Attached Schematic �y �U 2 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#/L-80 10,305'MD 10,142'TVD Packers and SSSV(type,measured and true vertical depth) Baker HP1-AH;N/A 10,285'MD 10,126'TVD 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: 44 31 0 650 150 Subsequent to operation: 49 37 0 350 250 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory Ill Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLLG❑ 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: 318-181 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: ' Operations Manager Contact Email: tkramerta'�hilcoro.con�i Authorized Signature: Ci�irC� . Date:r/50 ( Contact Phone: 777-8420 Form 10-404 Revised 4/2017 RBDMS12NiAY 3 12018 A."6 1,7 Submit Original Only • • Hilcorp Alaska, LLC Well Oerati nsSummaryr Y Well Name Rig API Number Well Permit Number Start Date End Date SCU 332-04 SL/E-Line 50-133-10107-00 160-019 5/8/18 5/11/18 Daily Operations: 05/08/2018-Tuesday Sign in at office fill out JSA and work permit. Pick up equipment on bull rail, travel to well site. Spot and rig up equipment. Stab on p/t 500/2,500psi, test good. RIH w/ paraffin scratcher 0-200'very sticky 200'-2,300' tools fell easy. POOH. RIH w/2-3/8" Helix cutter to 3,000'. POOH. Hard paraffin from surface to 1,350'. RIH w/ 10' 1.75" bailer while hot oil truck flushed 10bbls of hot water, tag X-nipple @ 10,297'KB. Unable to work through. POOH. Pulling heavy @ 3,300' 800#over. P/u weight. RIH w/ 1.75" gauge ring, was able to beat through nipple tag @ 10,409' KB w/t but still hanging up, but able to pass nipple @ 200+fpm would bobble through. RIH w/ 1.75" gauge ring on bottom of 1-11/16" dummy gun, unable to get past 660' KB from paraffin. Call for hot oil truck. RIH w/full bore spiral scratcher after hot oil pump 10bbls. RIH to 3,500'. Made passes from 500'-3500'. POOH. RIH w/ 1-11/16" dummy guns, able to bobble through X-nipple @ 10,297' KB but only 200+fpm. Call and talk with Billy on working through nipple more. 000H, r/d slickline, turn in permits, sign out and travel to PWL shop. 05/09/2018 -Wednesday Arrive @ PWL, gather tools, depart for Swanson River. Arrive @ Swanson River, talk w/company rep, sign permits. TGSM. Rig up on well. RIH w/ 1.75" x 2' broach to 10,299' KB, w/t fall through to 10,409' KB, tag bottom. After several pass attempts cant set down anymore at 10,299' KB. POOH. RIH w/ 10' 1-11/16" dummy guns w/ 1.75" g-ring to same. Can fall through after spanging, will not fall through without spangs. POOH. RIH w/ 10' 1-11/16" dummy guns w/ no B- ring to same. Same outcome. POOH. RIH w/2-3/8" braided line, brush to 10,299' KB, w/t fall through, pull back up through tubing tail, gain 500 extra lbs for 30'. Lose extra weight @ 10,271' KB. Make several passes with same outcome. POOH. RIH w/ 1.75" LIB to 10,291' KB, w/t POOH. OOH w/clear wire marks on LIB.Talk w/company rep, decide to lay down and bring fishing equipment out for tomorrow. Rig up with 160 wire. Found out there are SL tools and line in well. Rig down equipment. Move to 32C-15. 05/10/2018-Thursday Arrive SR meet w/ Billy A. TGSM JSA permit, discuss plan forward. Rig up .160" wire PT lub & WLV's to 2,000psi. Good. RIH w/ 1.87" lib to 10,271' KB. Sit, hit 2 times. POOH w/ impression of deflector on GLM. RIH w/2" RB baited w/5' stem 1.8" wire finder w/single prong wire grab w/t from 10,271' KB to 10,282' KB, latch wire. Pull up 1,800#several times, shear off. POOH. RIH w/2" SB to 10,273' KB latch w/tool several jar licks to 3,300#, shear off. POOH. RIH w/2" SB to 10,273' KB latch, w/tool, 4 jar licks to 3,300#, shear off. POOH. Dogs shucked on SB, discuss plan forward. Lay down lub, cut wire, re-head tie rope socket, secure well for night. • Hilco , Well OperatirpAlaskaons Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 332-04 SL/E-Line 50-133-10107-00 160-019 5/8/18 5/11/18 Daily Operations: 05/11/2018 - Friday Arrive SR meet w/ Billy A.TGSM JSA permit discuss plan forward. Rig up .160" wire PT lub & WLVs to 2,000psi, good. RIH w/ 1.87" LIB to 10,271' KB, sit hit 2 times. POOH w/ impression of deflector on glm. RIH w/2" RB baited w/5' stem 1.8" wire finder w/single prong wire grab wit from 10,271' KB to 10,282' KB, latch wire. Pull up 1,800#several times shear off., POOH. RIH w/2" SB to 10,273' KB latch w/tool several jar licks to 3,300#, shear off. POOH. RIH w/2" SB to 10,273' KB latch, w/tool, 4 jar licks to 3,300#, shear off. POOH. Dogs shucked on SB. Discuss plan forward. Lay down lub, cut wire, re-head tie rope socket, secure well for night. Pollard slickline will be sending me the info on the fish we have in the well tomorrow. I will get it together so we can get a schematic made up with up to date info. • 14 Soldotna Creek Unit ell SCU 332-04 SCU 332-04 As Completed 10/4/96 Hiicor')Alaska,LLC RKB:180'IGL:165'AMSL Casing and Tubing Detail RKB-THF:18.59'KB 1 ,'4 Size Type Wt/Grade Top Btm CONN/ID Cement/Other zz@ V' 30'20 € ' i ei 22" Structural Surface 15' cemented 13-3/8" Surface 54.5#,J-55 Surface 1,469' 8rd STC/12.615" 1,100 sxs cement ' 43.5#, N-80 Surface 186' 8rd LTC/8.755" 13-3/8" 9-5/8" Intermediate 47#, N-80 186' 3,661' 8rd LTC/8.681" 350 sxs cement @1,as9 r a CO-, 2 2�OC�ammi40#, N-80 3,661' 4,120' 8rd LTC/8.835" 23#, N-80 Surface 1,667' 8rd LTC/4.670" 9-5/8"@ 20#, N-80 1,667' 3,897' 8rd LTC/4.778" 600 sxs cement(15'stage) 4,122' I, 5-1/2" Production 17#, N-80 3,897' 6,964' 8rd LTC/4.892" I 20#, N-80 6,964' 9,459' 8rd LTC/4.778" 500 sxs cement(2nd stage) TOC @V 23#, N-80 9,459' 11,119' 8rd LTC/4.670" 6,375' Tubing k 2-3/8" Production 4.6#, N-80 Surface 10,306' Butt/1.995" 24 2-3/8" Production 4.6#, N-80 10,452' 10,515' Butt/1.995" roc@ -11: 2-3/8" Production 4.7#, N-80 10,515 10,833' EUE 8rd/1.995" ; 8,100' ;; �if 3 Production String Jewelry Detail SL W re 103:::4 4 # Depth(RKB) Length ID OD Item 10,273' 5/11/18 5 1 18.59' 0.58' 1.995" Tubing Hanger w/CIW type H BPV ' ii 6 GLM @ 2,059',3,124',4,113'5,093',6,048', TyonekG-2 2 6.25'(+/-) 1.901" 4.25" 6,760',7,473',8,127',8,778',9,428', 10,113' 2A 7,516' DV Collar i 3 10,284' .85' 2.50" 3.75" Baker K Anchor SL Tag@ t ,) ) See sh 4 10,285' 7.22' 2.390" 4.375" Baker HP1-AH Packer 10,409'SLM ► `?► . 7 Fi Detail @ 1.75"DcvGR 8 btmot 5 10,299' .73' 1.875" 2.875" X-Nipple (5/10/18) *,e. . 9 page 6 10,305' .67' 1.995" 2.875" Wireline Re-entry 4,i 7 10,453' 4.475' 2.688" 4.57" Baker SC-2P Packer PX plug set lr 3-i 8 10,457' 5.53' 2.995" 3.50" Baker Millout Extension i@1o502e 10 9 10,476' 4.04' 1.875" 3.10" Sliding Sleeve CMU 11 10 10,502' .75' 1.875" 3.10" X-Nipple(PX Plug set in same on 9/19/96) 12 11 10,510 3.98' 1.995" 4.125" Baker Telescoping Joint Tubing cut_ -i @10,515' ' . 12 10,515' 2.82' 2.441" 2.90" Bowen 150 Overshot w/Grapple 13 10,530' 3.92' 3.10" Brown HS-16-1 Packer t 14 10,600' 13.07' 2-3/8"Camco MM GLM a t ► 13 15 10,643' 3.92' Brown HS-16-1 Packer 16 10,662' 1.47' Otis S Nipple Position 1 Possible tubing ''' 14 17 10,723' 13.0' 2-3/8"Camco MM GLM leak @10,630.35', 18 10,766' .89' Camco D Nipple ig ►, -.7-- 15 19 10,768' Baker Model F Packer ,r. II 20 10,833' Tubing Tail with Muleshoe x 0 A 16 Perforation Data .{ ZONE TOP BTM Shot Condition Fish i 4 Pert 8/18/96[Repert 10/3/96, 12/13/00, @10,708 F ,17 G-2 10,388' 10,423' 6spf 3/10/02,3/05/03, 11/13/03, 11/28/04,5/01/05, 2/28/09,2/08/14] 10,450' 10,450' Isolated by PX plug-Active 10,470' 10,495' Isolated by PX plug-Active 118 10,509' 10,525' Isolated by PX plug-Active ►! ► 18 10,542' 10,630' Isolated by PX plug-Active t Hemlock 10,655' 10,713' Isolated by PX plug-Active 20 10,721' 10,764' Isolated byPX plugActive y t* 10,779' 10,825' Isolated by PX plug-Active ` 4,, > X4,4-'' 10,833' 10,875' Isolated by PX plug-Active 5-1/2"@ .,,.:1,#r 11,119' +� Well Data TD=11,119'MD/10,932'TVD PBTD=10,438'MD/10,275'TVD PTD: 160-019 API: 50-133-10107-00 Fish Detail: i Lease: FEDA-028997 Top Fish-Approx 116'of.125 SL wire,23'tool string,wire grab.5'wt. 1 Spud Date:3/30/1960 bar,rope socket,wire grab,wire finder,5'wt.bar,rope socket per 11/20/16 i Tree cxn: 2.5"Bowen WSR.See Drawing. Lift Threads(Short String): 2-3/8"IBT il Bottom Fish-Temp Sub&Spinner Tagged @ 10,708'on 9/14/87. 1 Lift Threads(Long String): 2-3/8"IBT SCU 332-04 Schematic 05-18-18 Updated by DMA 05-18-18 OF TF1 • • THE STATE Alaska Oil and Gas ��►:'i��, of® TT Conservation Commission __ = 333 West Seventh Avenue littArGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 - Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 �►N IP �� Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil and G Pool, SCU 332-04 Permit to Drill Number: 160-019 Sundry Number: 318-181 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions o d>!tions of approval set out in pp 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 s � DATED this t day of May, 2018. RBDMS A� U 12018 E . • 0 STATE OF ALASKA APR 26 €01 ALASKA OIL AND GAS CONSERVATION COMMISSION ej?S slit l s' APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend El Perforate Q ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well El Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0- 160-019° 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: - Anchorage Alaska 99503 50-133-10107-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123A Soldotna Creek Unit(SCU)332-04 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028997 • Swanson River Field/Hemlock Oil&G Zone 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): 11,119' , 10,932' - 10,438' 10,275' —1,098psi 10,502' 10,708'(fish) Casing Length Size MD TVD Burst Collapse Structural 15' 22" 15' 15' Conductor Surface 1,469' 13-3/8" 1,469' 1,469' 2,730 psi 1,130 psi Intermediate 4,120' 9-5/8" 4,120' 4,119' 5,750 psi 3,090 psi Production 11,119' 5-1/2" 11,1196' 10,932' 7,740 psi 6,390 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 10,305' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker HP1-AH;N/A 10,285'MD/10,125'TVD;N/A;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development p Service ❑ 14.Estimated Date for 15.Well Status after proposed work: May 10,2018 Commencing Operations: OIL ❑r - WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 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 ,�� b Contact Phone: 777-8420 % Authorized Signature: �/�-1 Date: f/1„�(O COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: A S— 131 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: RBDMSLILIAY 0 1 2018 Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ No li Subsequent Form Required: /O_ y O t APPROVED BY t i f`e.> Approved by: 60.,__QC/N-s."----- COMMISSIONER THE COMMISSION Date: SIJ` \�� 1. /o'l 1 NAL ubmd Form and 8 Form 10-403 Revised 4/2017 Approved appli rliiAv li r m h fffTTT666FRRR»>the date of approval. Attachments in Duplicate • • Well Prognosis Well: SCU 332-04 Hilearp Alaska,Ida Date:4/24/2018 Well Name: SCU 332-04 API Number: 50-133-10107-00 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: May 10th, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-019 First Call Engineer: Ted Kramer (907)777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,200 psi @ 10,234' TVD (Based on pressure survey ran in well on 4/29/13 at 10,400' MD.) Maximum Expected BHP: — 1,200 psi @ 10,234' TVD (Estimate based on offset wells in the on 4/29/13 at 10,400' MD.) Max. Potential Surface Pressure: — 1,098 psi (Based on actual reservoir conditions Minus 0.1 psi/ft) Brief Well Summary Swanson River Unit 332-04 (originally permitted as SRU 32-04) was drilled as a grassroots in 1960. The well was converted to gas injection in 1967. The Hemlock intervals were isolated with a PX plug and the well recompleted in the Tyonek G in 1996. The Tyonek G has been re-perforated several times, including 2000,2003, 2004, 2005, and 2009. This work covered by this Sundry is to add Perforations in the G-1 sand. Notes Regarding Wellbore Condition • The last fill tag depth showed fill close to the bottom of the perforated interval at 10,421'SLM. • Tree connection is 2.5" Bowen. OBJECTIVE OF Wellwork Perforate the Tyonek G-1. E-line Procedure: 1. MIRU e-line unit. Pressure Test lubricator to 3,500 psi Hi 250 Low. 2. PU and RIH with perf guns. Log on depth and perforate the following intervals. Zone Sands Top (MD) Btm (MD) FT Tyonek G-1 ±10,334' ±10,354' 20' 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. 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. II • • Well Prognosis Well: SCU 332-04 Hiicory Alaska,LLQ Date:4/24/2018 Attachments: 1. As-built Schematic 2. Proposed Schematic Ildotna • Soldotna CreekUnit eCreek Unit ll SCU 332 04 SCU 33204 Completed 10/4/96 StUpi'.. H • Hiicorp Alaeka,LLC RKB:19o'/GL:165'AMSL Casing and Tubing Detail RKB-THF:18.59'KB s t 1 ,r Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22"@h. 22" Structural Surface 15' cemented 30' i "i 13-3/8" Surface 54.5#,J-55 Surface 1,469' 8rd STC/12.615" 1,100 sxs cement §t; aii, 43.5#, N-80 Surface 186' 8rd LTC/8.755" Ji 13-3/8" 9-5/8" Intermediate 47#, N-80 186' 3,661' 8rd LTC/8.681" 350 sxs cement @1,469' �j " Tom@ 40#, N-80 3,661' 4,120' 8rd LTC/8.835" Pll 20 2.835' 23#, N-80 Surface 1,667' 8rd LTC/4.670" 20#, N-80 1,667' 3,897' 8rd LTC/4.778" 600 sxs cement(1s`stage) 9-5/8"@ 5-1/2" Production 17#, N-80 3,897' 6,964' 8rd LTC/4.892" 4,122' 20#, N-80 6,964' 9,459' 8rd LTC/4.778" 500 sxs cement(2nd stage) TOC @ 23#, N-80 9,459' 11,119' 8rd LTC/4.670" 6,375' i mmili Tubing 2-3/8" Production 4.6#, N-80 Surface 10,306' Butt/1.995" 2-3/8" Production 4.6#, N-80 10,452' 10,515' Butt/1.995" 1 2A 2-3/8" Production 4.7#, N-80 10,515 10,833' EUE 8rd/1.995" TOC @Production String Jewelry Detail 8,100' t M 3 47 01,7_41 4 # Depth(RKB) Length ID OD Item 1 18.59' 0.58' 1.995" Tubing Hanger w/CIW type H BPV 2 6.25'(+/-) 1.901" 4.25" GLM @ 2,059',3,124',4,113'5,093',6,048', 6,760',7,473',8,127',8,778',9,428', 10,113' #"+ TyonekG-2 2A 7,516' DV Collar SL Tag @ '4 3 10,284' .85' 2.50" 3.75" Baker K Anchor 10,438'SLM - ,, �, 4 10,285' 7.22' 2.390" 4.375" Baker HP1-AH Packer `� L*;i4": 7 5 10,299' .73' 1.875" 2.875" X-Nipple 1.75"B Box + (10/10/14) N"'£:a 8 6 10,305' .67' 1.995" 2.875" Wireline Re-entry 4.tz' 9 I 7 10,453' 4.475' 2.688" 4.57" Baker SC-2P Packer ..„ ..,:.J8 10,457' 5.53' 2.995" 3.50" Baker Millout Extension PX plug set ^r inXNipple 10 9 10,476' 4.04' 1.875" 3.10" Sliding Sleeve CMU @10,502' `4 10 10,502' .75' 1.875" 3.10" X-Nipple(PX Plug set in same on 9/19/96) € 11 11 10,510 3.98' 1.995" 4.125" Baker Telescoping Joint Tubing cut 12 12 10,515' 2.82' 2.441" 2.90" Bowen 150 Overshot w/Grapple @10,515' i 13 10,530' 3.92' 3.10" Brown HS-16-1 Packer 14 10,600' 13.07 2-3/8"Camco MM GLM _ _ 15 10,643' 3.92' Brown HS-16-1 Packer '. . 13 16 10,662' 1.47' Otis S Nipple Position 1 F 17 10,723' 13.0' 2-3/8"Camco MM GLM Possible tubing I' 18 10,766' .89' Camco D Nipple leak @10,630-35'i 19 10,768' Baker Model F Packer ® s_ 15 20 10,833' Tubing Tail with Muleshoe #' Perforation Data tx ZONE TOP BTM Shot Condition `{ Perf 8/18/96[Reperf 10/3/96, 12/13/00, Fish 4,` G-2 10,388' • 10,423' 6spf 3/10/02,3/05/03, 11/13/03, 11/28/04,5/01/05, @l0,708' „ 2/28/09,2/08/14] 10,450' 10,450' Isolated by PX plug-Active " 10,470'' 10,495' Isolated by PX plug Active 10,509' 10,525' Isolated by PX plug-Active 10,542' • 10,630' Isolated by PX plug-Active >�® e< 18 Hemlock 10,655' ' 10,713' Isolated by PX plug-Active f 20 10,721' - 10,764' Isolated by PX plug-Active w' 10,779' . 10,825' Isolated by PX plug-Active 10,833' 10,875' Isolated by PX plug-Active 5- d I> 11,x1 ' 3 Well Data 11,119' P TD=11,119'MD/10,932M/D APD: 160-019 PBTD=10,438'MD/10,275'ND API: 50-133-10107-00: FEDA-028997 Lease: FEDA28997 Spud Date:3/30/1960 Fish Detail: Tree cxn: 2.5"Bowen • Left Temp Sub&Spinner,tagged @ 10,708' on 9/14/87 Lift Threads(Short String): 2-3/8"IBT Lift Threads(Long String): 2-3/8" IBT SCU 332-04 Schematic 04-25-18 Updated by DMA 04-25-18 ROPOSED SCHEMA IC weld/scu Creek Unit r SCU 332-OAF z.s Completed 10/4/96 lilIi cure Alaska,LLC RKB:180'/GL:165'AMSL CASING DETAIL RKB-THF:18.59'FCB Size Type Wt/Grade Top Btm CONN/ID Cement/Other 1 - • 22" Structural Surface 15' cemented 22" �@@ 1 A .4 13-3/8" Surface 54.5#,J-55 Surface 1,469' 8rd STC/12.615" 1,100 sxs cement 3 43.5#,N-80 Surface 186' 8rd LTC/8.755" ter 'so 9-5/8" Intermediate 47#,N-80 186' 3,661' 8rd LTC/8.681" 350 sxs cement 13-3/8" ill404,N-80 3,661' 4,120' 8rd LTC/8.835" @ 1469' . 2 = TOC @ 23#,N-80 Surface 1,667' 8rd LTC/4.670" 2,835' 204,N-80 1,667' 3,897' 8rd LTC/4.778" 600 sxs cement(1st stage) 9-5/8"@ y 5-1/2" Production 174,N-80 3,897' 6,964' 8rd LTC/4.892" 4,122' 204,N-80 6,964' 9,459' 8rd LTC/4.778" 500 sxs cement(2nd stage) 23#,N-80 9,459' 11,119' 8rd LTC/4.670" TOC@ , TUBING DETAIL 6,375' 2-3/8" Production 4.6#,N-80 Surface 10,306' Butt/1.995" 2-3/8" Production 4.6#,N-80 10,452' 10,515' _ Butt/1.995" y ' j 2A 2-3/8" Production 4.7#,N-80 10,515 10,833' EUE 8rd/1.995" TOC@ 3 JEWELRY DETAIL 8,100' «)" :` . q # Depth(RKB) Length ID OD Item 6 1 18.59' 0.58' 1.995" Tubing Hanger w/CIW type H BPV 6 2 6.25'(+/-) 1.901" 4.25" GLM @ 2,059',3,124',4,113'5,093',6,048',6,760', kt G 1 7,473',8,127',8,778',9,428',10,113' ot 2A 7,516' DV Collar SL Tag@ i -G-2 3 10,284' .85' 2.50" 3.75" Baker K Anchor 10,438'SLM , S,°1,2 ,zi 4 10,285' 7.22' 2.390" 4.375" Baker HP1-AH Packer c 1.75"B-Box ....":„V 7 (10/10/14) � £;',� $ 5 10,299' .73' 1.875" 2.875" X-Nipple V kr 9 6 10,305' .67' 1.995" 2.875" Wireline Re-entry " 7 10,453' 4.475' 2.688" 4.57" Baker SC-2P Packer PX plug set s,, 8 10,457' 5.53' 2.995" 3.50" Baker Millout Extension inXNipple =. 10 9 10,476' 4.04' 1.875" 3.10" Sliding Sleeve CMU @ 10,502' la 11 10 10,502' .75' 1.875" 3.10" X-Nipple(PX Plug set in same on 9/19/96) Tubing cuter " 12 11 10,510 3.98' 1.995" 4.125" Baker Telescoping Joint @10,515' 12 10,515' 2.82' 2.441" 2.90" Bowen 150 Overshot w/Grapple '0 13 10,530' 3.92' 3.10" Brown HS-16-1 Packer 14 10,600' 13.07' 2-3/8"Camco MM GLM ii_i 13 15 10,643' 3.92' Brown HS-16-1 Packer �i 16 10,662' 1.47' Otis S Nipple Position 1 Possible tubing "14 17 10,723' 13.0' 2-3/8"Camco MM GLM leak @ 10,630-35', , 18 10,766' .89' Camco D Nipple 15 19 10,768' Baker Model F Packer xf a 16 20 10,833' Tubing Tail with Muleshoe .r+ PERFORATION DETAIL Fish i"° •4 ZONE TOP BTM Shot Condition @10,708' r. „17 G-1 ±10,334' ±10,354' Proposed G-2 10,388' 10,423' 6spf Perf 8/18/96[Reperf 10/3/96,12/13/00,3/10/02,3/05/03,11/13/03, 11/28/04,5/01/05,2/28/09,2/08/14] 17) 10,450' 10,450' Isolated by PX plug-Active 18VI 18 10,470' 10,495' Isolated by PX plug Active ,if lom-4 III or: 10,509' 10,525' Isolated by PX plug-Active or 20 10,542' 10,630' Isolated by PX plug-Active Hemlock 10,655' 10,713' Isolated by PX plug-Active Rei 10,721' 10,764' Isolated by PX plug-Active '' 1„1444Z44& 10,779' 10,825' Isolated by PX plug-Active 5-1/2"@ i.;... 11,119' 10,833' 10,875' Isolated by PX plug-Active TD=11,119'MD/10,932'TVD Well Data PBTD=10,438'MD/10,275'TVD PTD:160-019 API: 50-133-10107-00 Fish Detail: t Lease: FEDA-028997 • Left Temp Sub& Spinner,tagged @ 10,708' on 9/14/87 Spud Date:3/30/1960 Tree cxn: 2.5"Bowen Lift Threads(Short String): 2-3/8"IBT SCU 332-04 Proposed Schematic 04-25-18 Updated by DMA 04-25-18 Lift Threads(Long String): 2-3/8"IBT UNSCANNED, OVERSIZED MATERIALS AVAILABLE: Q(9' FILE # To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission +333 W. 7th Ave., Ste. 100 R Anchorage, Alaska 99501 Voice (907) 279-1433 ~ Fax (907) 276-7542 RECEIVED STATE OF ALASKA ALh.,,.A OIL AND GAS CONSERVATION COMMISSION MAR 0 6 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations AOGCC Repair Well U Plug Perforations U Perforate U Other U Reperforate Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program El 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 E Exploratory ❑ • 50-133-10107-00 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic Service ❑ 6.API Number: Anchorage,Alaska 99503 160-019 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028997 Soldotna Creek Unit(SCU)332-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil&G-Zone 11.Present Well Condition Summary: Total Depth measured ' 11,119 feet Plugs measured 10,502 feet true vertical 10,932 feet Junk measured 10,708 feet Effective Depth measured - 11,031 feet Packer measured 10,285 feet true vertical 10,846 feet true vertical 10,126 feet Casing Length Size MD TVD Burst Collapse Structural 15' 22" 15' 15' Conductor Surface 1,469' 13-3/8" 1,469' 1,469' 2,730 psi 1,130 psi Intermediate 4,120' 9-5/8" 4,120' 4,119' 5,750 psi 3,090 psi Production 11,119' 5-1/2" 11,119' 10,932' 7,740 psi 6,390 psi Liner Perforation depth Measured depth See Attached Schematic MAY True Vertical depth See Attached Schematic SCANNED MAY 2 12014 Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#/L-80 10,305'MD 10,142'ND Packers and SSSV(type,measured and true vertical depth) Baker HP1-AH;N/A 10,285'MD 10,126'TVD 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 RBDMSq MAY 1 4 2014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 12 70 0 365 150 - Subsequent to operation: 20 9 0 440 150 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0. Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil . 2 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: 314-058 Contact Stan Porhola Email sporholaOhilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature , Phone 907-777-8412 Date 3/60Y' Form 10-404 Revised 10/2012 A-$/24717 Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 332-04 50-133-10107-00 160-019 2/8/14 2/8/14 Daily Operations: 02/08/2014-Saturday Pressure test lubricator to 250 psi low and 3,000 psi high. TP: 180 psi. RIH and run strip CCL/GR log from 10,500' to 10,200' and send to town for perf depth. Perforated from 10,388'to 10,423'with 1-9/16" HC, 6 spf, 60 deg phase perf gun. Made two runs and tubing pressure did not change. Rig down and turn well over to production. • Soldotna Creek Unit SCU 332-04 IHIMItIlilcoce Casing and Tubing Detail RKB:180'/GL:165'AMSL RKB-THF:1859'KB Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22"@ 0 22" Structural Surface 15' cemented 30' 13-3/8" Surface 54.5#,J-55 Surface 1,469' 8rd STC/12.615" 1,100 sxs cement -a 43.5#, N-80 Surface 186' 8rd LTC/8.755" AI co s 9-5/8" Intermediate 47#, N-80 186' 3,661' 8rd LTC/8.681" 350 sxs cement 13-3/8" @ 1,469' ° . TOC @ 40#, N-80 3,661' 4,120' 8rd LTC!8.835" n 2 2,835' 23#, N-80 Surface 1,667' 8rd LTC/4.670" a 20#, N-80 1,667' 3,897' 8rd LTC/4.778" 600 sxs cement(1st stage) 9-`/8"@ andis Illese. 5-1/2" Production 17#, N-80 3,897' 6,964' 8rd LTC/4.892" 4,122' '0 20#, N-80 6,964' 9,459' 8rd LTC/4.778" 500 sxs cement(2nd stage) ° 23#, N-80 9,459' 11,119' 8rd LTC/4.670" 6�@ 0 Tubing 9 2-3/8" Production 4.6#, N-80 Surface 10,306' Butt/1.995" • 2-3/8" Production 4.6#, N-80 10,452' 10,515' Butt/1.995" 0 ] 2A 2-3/8" Production 4.7#, N-80 10,515 10,833' EUE 8rd/1.995" Toc@ • 3 Production String Jewelry Detail 8,100' lo�� g 4 # Depth(RKB) Length ID OD Item • 1 18.59' 0.58' 1.995" Tubing Hanger w/CIW type H BPV OM 5GLM @ 2,059',3,124',4,113'5,093',6,048', 111 6C------.., 2 6.25'(+/-) 1.901" 4.25" 6,760',7,473',8,127',8,778', 9,428', 10,113' ekG-2 ' 2A 7,516' DV Collar EL Tag @ 3 10,284' .85' 2.50" 3.75" Baker K Anchor 1o,45aKBELM 4 10,285' 7.22' 2.390" 4.375" Baker HP1-AH Packer 1-9/16"Guns _iits.j7 5 10,299' .73' 1.875" 2.875" X-Nipple (2/08/14) 8 6 10,305' .67' 1.995" 2.875" Wireline Re-entry 9 7 10,453' 4.475' 2.688" 4.57" Baker SC-2P Packer •• 8 10,457' 5.53' 2.995" 3.50" Baker Millout Extension nXNi set i 9 10,476' 4.04' 1.875" 3.10" Sliding Sleeve CMU n X Nipple 10 @10,502' 11 10 10,502' .75' 1.875" 3.10" X-Nipple(PX Plug set in same on 9/19/96) ` 1 11 10,510 10,515' 3.98' 1.995" 4.125" Baker Telescoping Joint Tubing cut 12 2.82' 2.441" 2.90" Bowen 150 Overshot w/Grapple @105 ►l 112 15' 13 10,530' 3.92' 3.10" Brown HS-16-1 Packer 14 10,600' 13.07' 2-3/8"Camco MM GLM 13 15 10,643' 3.92' Brown HS-16-1 Packer ® rE 16 10,662' 1.47' Otis S Nipple Position 1 17 10,723' 13.0' 2-3/8"Camco MM GLM Possible tubing , -.--3,14 18 10,766' .89' Camco D Nipple eak@1o,630-35' ' ► 19 10,768' Baker Model F Packer ® B 15 20 10,833' Tubing Tail with Muleshoe 16 Perforation Data ZONE TOP BTM Shot Condition sh Perf 8/18/96[Reperf 10/3/96, 12/13/00, Fi @1Fi hoe'- p, p 17 G-2 10,388' 10,423' 6spf 3/10/02,3/06/03,4.1/13/03, 11/28/04,5/01/05, 2/28/09�2/08/14� 10,450' 10,450' Iso`Tafed by PX plug-Active 10,470' 10,495' Isolated by PX plug-Active ' 18 10,509' 10,525' Isolated by PX plug-Active g 1s Hemlock 10,542' 10,630' Isolated by PX plug-Active 10,655' 10,713' Isolated by PX plug-Active 20 10,721' 10,764' Isolated by PX plug-Active 10,779' 10,825' Isolated by PX plug-Active 10,833' 10,875' Isolated by PX plug-Active 5-1/Z'@ I ,' . ;� 11119' Well Data PTD: 160-019 TD=11,119'MD/10,932'TVD API: 50-133-10107-00 PBTD=11,031'MD/10,846'TVD Lease: FEDA-028997 Spud Date:3/30/1960 Fish Detail: Tree cxn: 2.5"Bowen • Left Temp Sub&Spinner,tagged @ 10,708' on 9/14/87 Lift Threads(Short String): 2-3/8"IBT Lift Threads(Long String): 2-3/8"IBT SCU 332-04 Actual Schematic 2-08-14 Updated by STP 2/25/14 • ,Aii/7 THE STATE A _c ; LD:r P 5 7---- -,:-=',6::z.:-; — 330 West Seven fa venue 16':""1.:- / GON'ERNOR SEAN DAt'N1:H Anchorage Alaskn7 99501 3572 °,='-') ,,, oc3'f 9P7 279 i33 6 2 SCOWSCOW �IA�` I14 Stan Porhola Operations Engineer Hilcorp Alaska, LLC _ f cli 3800 Centerpoint Drive, Suite 100 Qd Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 332-04 Sundry Number: 314-058 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P)zei.),/, ....._ Cathy P. oerster Chair DATED this-211/4y of February, 2014. Encl. RECEIVED STATE OF ALASKA JAN 2 7 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Weil❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Re.—Perforate❑✓ , Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ After Casing❑ Other.❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development ❑✓ 160-019 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10107-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 1236 • Soldotna Creek Unit(SCU)332-04 • Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): A028997 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): /ON :''D.?14 /07V7- . Y- ii Casing Length Size MD ND Burst Collapse Structural Conductor 30' 22" 30' 30' Surface 1,469' 13-3/8" 1,469' 1,469' 2,730 psi 1,130 psi Intermediate Production 4,122' 9-5/8" 4,122' 4,121' 5,750 psi 3,090 psi Liner 11,136' 5-1/2" 11,136' 10,951' 7,740 psi 6,390 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.7#/L-80 10,306' Packers and SSSV Type: Packers and SSSV MD(ftt)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: • Detailed Operations Program I I BOP Sketch I I Exploratory I I Stratigraphic I I Development 1 4 1 Service 14.Estimated Date for 15.Well Status after propcosed work: Commencing Operations: 01/31/14 Oil Q • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporhola@hilcorp.com Printed Name tan Porti a Title Operations Engineer / Signature l2'-. Phone 907-777-8412 Date /2.n t//f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3I (--1-0‘—A1 El Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: RBDMSMAY 0 9 2014 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /6 - y o y g.„.) 1 APPROVED BY Approved by: ...„._ i7 COMMISSIONER THE COMMISSION Date: i— /,/�/�_ ^r 'IC/ Submit Form and k,\ Form 10-403(Revised 10/2012) Appro a +�((t o//��2 onths frtfm the date of approval. Attachments in Duplicate .�,` 1 /`'1 SIL -F0rD15 aI'I)y , c- vy y Well Prognosis Well: SCU 332-04 Hilcorp Alaska,LI) Date: 1/27/2014 Well Name: SCU 332-04 API Number: 50-133-10107-00 • Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: January 31st, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-019 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,200 psi @ 10,234' TVD (Based on pressure survey ran in well on 4/29/13 at 10,400' MD.) Maximum Expected BHP: — 1,200 psi @ 10,234' TVD (Estimate based on offset wells in the on 4/29/13 at 10,400' MD.) Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 25% (0.380psi/ft) Brief Well Summary Swanson River Unit 332-04 (originally permitted as SRU 32-04) was drilled as a grassroots in 1960. The well was converted to gas injection in 1967. The Hemlock intervals were isolated with a PX plug and the well recompleted in the onek G in 1996.,The Tyonek G has been reperforated several times, including 2000, 2003, 2004, 2005, and 2009. The we a known paraffin producer and the well has stopped-producing fluid. The perforations have likely plugged off with paraffin. Plan is to reperforate the Tyonek G to re-open communication to the formation. Notes Regarding Wellbore Condition • The last fill tag depth showed fill close to the bottom of the perforated interval at 10,421'SLM. OBJECTIVE OF WORKOVER Re-perforate the Tyonek G to re-establish connectivity with the reservoir. E-line Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 2. RU 1.6875" (1-11/16") 6.0 spf 0 deg strip guns. 3. RIH and re-perforate Tyonek G interval from 10,388'-10,423'. a. Perforating depths pending slickline cleanout of existing fill. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact pen intervals. d. Correlate using GR/CCL Log dated 10/03/96(Tie-in log depth is 10,388'-10,423'). e. No Gamma/Pressure/Temperature tool. f. Record tubing pressures before and after each perforating run. ,/ 4. RD E-line. 5. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic • Soldotna Creek Unit SCU 332-04 -MEM TAIrililellorD Casing and Tubing Detail RT-THF:18.59'KB 1 Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22"@ I 22" Structural Surface 30' cemented 30' 13-3/8" Surface 54.5#,J-55 Surface 1,469' 8rd STC/12.615" 1,100 sxs cement 43.5#, N-80 Surface 186' 8rd LTC/8.755" 9 5/8" Surface 47#, N-80 186' 3,661' 8rd LTC/8.681" 350 sxs cement 13318" • @1,469' TOC@ 40#, N-80 3,661' 4,122' 8rd LTC/8.835" 0 2 2,835' 23#, N-80 Surface 1,667' 8rd LTC/4.670" 20#, N-80 1,667' 3,897' 8rd LTC/4.778" 600 sxs cement(1st stage) %S8"@ 5-1/2" Liner 17#, N-80 3,897' 6,964' 8rd LTC/4.892" 4,122' 4 20#, N-80 6,964' 9,459' . 8rd LTC/4.778" 500 sxs cement(2nd stage) TOC @ 23#, N-80 9,459' 11,119' 8rd LTC/4.670" 6,375' . 0 Tubing 2-3/8" Production 4.7#, N-80 18.59' 10,306' Butt/1.995" 2-3/8" Production 4.7#, N-80 10,452' 10,515' Butt/1.995" L ° ] 2A 2-3/8" Production 4.7#, N-80 10,515 10,833' EUE 8rd/1.995" TOC@ ' 3 Production String Jewelry Detail 8,100' ® l'. 4 # Depth(RKB) Length ID OD Item 1 18.59' .58' 1.995" _ Tubing Hanger w/CIW type H BPV SL Tag@ Z 5 GLM @ 2,059',3,124',4,113'5,093',6,048', 10,421'KBSLM• - 6 2 6.25'(+/-) 1.901" 4.25" 6,760', 7,473',8,127',8,778',9,428', 10,113' 2.0a'cR 2A 7,516' DV Collar (12/31/13) -. Tagged fill @ 3 10,284' .85' 2.50" 3.75" Baker K Anchor 10448'ELM '. ", - 4 10,285' 7.22' 2.390" _ 4.375" Baker HP1-AH Packer (2128/09) g ;4-'- 7 5 10,299' .73' 1.875" 2.875" _ X-Nipple 8 6 10,305' .67' • 1.995" _ 2.875" Wireline Re-entry 9 7 10,453' 4.475' 2.688" _ 4.57" Baker SC-2P Packer 8 10,457' 5.53' 2.995" _ 3.50" Baker Millout Extension PnXN9 e 9 10,476' 4.04' . 1.875" 3.10" Sliding Sleeve CMU @10,502' �� 10 10,502' .75' 1.875" 3.10" X-Nipple(PX Plug set in same on 9/19/96) 11 10,510 3.98' 1.995" 4.125" Baker Telescoping Joint Tubing cut�� 12 12 10,515' 2.82' 2.441" _ 2.90" Bowen 150 Overshot w/Grapple @10,515' 13 10,530' 3.92' 3.10" _ Brown HS-16-1 Packer 14 10,600' 13.07' 2-3/8"Camco MM GLM ® 13 15 10,643' 3.92' _ Brown HS-16-1 Packer IX 16 10,662' 1.47' Otis S Nipple Position 1 17 10,723' 13.0' 2-3/8"Camco MM GLM Possible tubing 0 14 18 10,766' .89' Camco D Nipple eak@10,630-35' ' ► 19 10,768' _ Baker Model F Packer CE 15 20 10,833' Tubing Tail with Muleshoe 16 Perforation Data Fish 0,' _' ZONE TOP BTM Shot Condition @10,708' 0 17 G-2 10,388' 10,423' 6spf Reperfed 2/28/09 , 10,450' 10,450' Isolated by PX plug-Active 10,470' 10,495' Isolated by PX plug-Active 10,509' 10,525' Isolated by PX plug-Active 18 10,542' 10,630' Isolated by PX plug-Active ® pE 18 Hemlock 10,655' 10,713' Isolated by PX plug-Active 10,721' 10,764' Isolated by PX plug-Active 20 10,779' , 10,825' Isolated by PX plug-Active 10,833' 10,875' Isolated by PX plug-Active 5-112"@ I • ' •' � Fish Detail: 11,136' • Left Temp Sub& Spinner,tagged @ 10,708' on 9/14/87 TD=11,119'MD/10,932'TVD PBTD=11,031'MD/10,846'TVD SCU_332-04 Actual Schematic 1-23-14 Updated by STP 1/23/14 • Soldotna Creek Unit SCU 332-04 I:i;i:I1_ • corp Alaska,L Casing and Tubing Detail RT-THF:18.59'KB "'" .i.iii.. [ Size Type Wt/Grade Top - Btm CONN/ID Cement/Other 1 n" 22" Structural Surface 30' cemented 30' 13-3/8" Surface 54.5#,J--8505 Surface 1,469' 8rd STC/12.615" 1,100 sxs cement • 43.5#, N-80 Surface 186' 8rd LTC/8.755" 13-3i8„ 9-5/8" Surface 47#, N 186' 3,661' 8rd LTC/8.681" 350 sxs cement @1,469' :, TOC@ 40#, N-80 3,661' 4,122' 8rd LTC/8.835" 2 2,835' 23#, N-80 Surface 1,667' 8rd LTC/4.670" 20#, N-80 1,667' _ 3,897' 8rd LTC/4.778" 600 sxs cement(15'stage) 9-5/8"@ 5-1/2" Liner 17#, N-80 3,897' 6,964' 8rd LTC/4.892" 4,122' 20#, N-80 6,964' 9,459' 8rd LTC/4.778" 500 sxs cement(2nd stage) Toc @ 23#, N-80 9,459' 11,119' 8rd LTC/4.670" 6,375' Tubing 2-3/8" Production 4.7#, N-80 18.59' 10,306' Butt/1.995" 2-3/8" Production 4.7#, N-80 10,452' 10,515' Butt/1.995" 1 2A 2-3/8" Production 4.7#, N-80 10,515 10,833' EUE 8rd/1.995" Toc@ s F Production String Jewelry Detail 8,100' ® 4 # Depth(RKB) Length ID OD Item 1 18.59' .58' 1.995" Tubing Hanger w/CIW type H BPV SL Tag 5 2 6.25'(+/-) 1.901" 4.25" GLM @ 2,059', 3,124',4,113'5,093',6,048', 10,421'KBSLM 6 _ 6,760', 7,473',8,127',8,778', 9,428', 10,113' 2.120"cR (12/31/13) 2A 7,516' DV Collar Tagged fill @ 3 10,284' .85' 2.50" 3.75" Baker K Anchor 10,448'ELM , ..:'a. .`, `•%", 4 _ 10,285' 7.22' 2.390" 4.375" Baker HP1-AH Packer (2/28/09) ]dt-1a 7 5 10,299' .73' 1.875" . 2.875" X-Nipple 8 6 10,305' .67' 1.995" 2.875" Wireline Re-entry 9 7 10,453' 4.475' 2.688" 4.57" Baker SC-2P Packer 8 10,457' 5.53' 2.995" _ 3.50" Baker Millout Extension nxNPpe plug set , 9 10,476' 4.04' 1.875" 3.10" Sliding Sleeve CMU —I 10@1o,50z' 10 10,502' .75' 1.875" 3.10" X-Nipple(PX Plug set in same on 9/19/96) 11 10,510 3.98' 1.995" 4.125" Baker Telescoping Joint )12 12 10,515' 2.82' 2.441" . 2.90" . Bowen 150 Overshot w/Grapple Tubing cut........:__..(@10,515' 13 10,530' 3.92' 3.10" Brown HS-16-1 Packer 14 10,600' 13.07' 2-3/8"Camco MM GLM ® 13 15 - 10,643' 3.92' Brown HS-16-1 Packer 16 10,662' 1.47' _ Otis S Nipple Position 1 17 _ 10,723' 13.0' 2-3/8"Camco MM GLM Possible tubing 0 14 18 10,766' .89' Camco D Nipple eak @ 10,630-35' ► 19 _ 10,768' Baker Model F Packer ® C' 15 20 10,833' Tubing Tail with Muleshoe 16 Perforation Data Fish rye'- ZONE TOP BTM Shot Condition @10,708' .;r - 017 10,388' Reperfed 2/28/09(Proposed Re-Pert) .i 'f 10,450' 10,450' Isolated by PX plug-Active 41 10,470' 10,495' Isolated by PX plug-Active t 1 10,509' 10,525' _ Isolated by PX plug-Active VI -- 18 10,542' 10,630' Isolated by PX plug-Active g 18 Hemlock 10,655' 10,713' Isolated by PX plug Active — 10,721' 10,764' Isolated by PX plug-Active 20 10,779' 10,825' Isolated by PX plug-Active 10,833' 10,875' Isolated by PX plug-Active 5-1/2"@ I .' ;t, 11136 Fish Detail: • Left Temp Sub& Spinner,tagged @ 10,708' on 9/14/87 TD=11,119'MD/10,9321VD PBTD=11,031'MD/10,846'TVD SCU 332-04 Proposed Schematic 1-24-14 Updated by STP 1/24/14 STATE OF ALASKA -s~ ~~~ Y ~® ALA OIL AND GAS CONSERVATION COMM~ION REPORT OF SUNDRY WELL OPERATIONS MAR ~ ~ ~~~~ 1. Operations Abandon Repair Well Plug Perforations Stimulate er Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ ~~~~ Change Approved Program ^ Operat. Shutdown^ Perforate^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development^ Exploratory^ 160-019 - 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-133-10107-00 - 7. KB Elevation (ft): 9. Well Name and Number: 18.59' Soldotna Ck Unit (SCU) 332-04- 8. Property Designation: 10. Field/Pool(s): FEDA028997 [Swanson River Field] Swanson River Field /Hemlock Oil & G-Zone 11. Present Well Condition Summary: Total Depth measured 11,136 feet Plugs (measured) 10,502' true vertical 10,951 feet Junk (measured) N/A Effective Oepth measured 10,448 feet y;F , ~Y. ~ ~,~ ^~ !-1 ~ i ~ ~' ` ~ '~ ~~ty: SVfr -°, ~ true vertical feet ~ '` " Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 22" 30' 30' Surface 1,469' 13-3/8" 1,469' 1,469' 2,730 psi 1,130 psi Intermediate 4,122' 9-5/8" 4,122' 4,121' 5,750 psi 3,090 psi Production 11,136' S-1/2" 11,136' 10,951' 7,740 psi 6,280 psi Liner Perforation depth: Measured depth: 10,388'-10,423' True Vertical depth: Tubing: (size, grade, and measured depth) 2-3/8" 4.7#, L-80 Surf-10,306' & 10,452'-10,833' Packers and SSSV (type and measured depth) Baker HP1-,4H packer 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 17 bbl 0 0 bbl 700 psi (gas lift) 160 psi Subsequent to operation: 74 bbl - 0 0 bbl 675 psi (gas lift) 300 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Q - Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: N/A Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg ~ Title Drilling Manager Signature ~~ , ~ ~~ Phone 263-7600 Date 3/11/2009 ' sion Form 10-404 Revised 04/20({6 , ~ (' ~ ~ ~~ Cp Submit Original Only eVPO Soldotna Creek Unit Soldotna Creek Unit Well SCU 332-04 S(CU 332-Q'~ As Completed 10/4/96 RT-TFf: 18.99' FB ~° ~ r 3d 1 13318" ~ 1,463 ~ ' ~ TOC ~1 ~• 2 za3s .i 9518^ ~ 4,122 6,375' 2A TOC ~ 3 a,1oa - 4 5 6 Ta89edfill~ . 10,448' ~M .'':s~~ tif'?"~' ,' 8 (?128109) ``: ~` 7 i g PXpugset , ~,xN~le 10 ~1o,soz 11 Tut9ng cut : 12 ~1o,s1s 13 Fbssltletudng , 14 ealc~lo,sao-3s . 15 16 Asn >~ Lm1o,7oe n 18 18 20 5.112" ~ ~ ~'':: ~ ~~. ~' :.~ 11,136' TD =11,136'ND / 10,951'TVD PBTD =11,015'MD / 10,834 TVD Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 22" Structural Surface 30' cemented 13-3/8" Surface 54.5#, J-55 Surface 1,469' 8rd STC / 12.615" 1,100 sxs cement 43.5#, N-80 Surface 186' 8rd LTC / 8.755" 9-5/8" Surface 47#, N-80 186' 3,661' 8rd LTC / 8.681" 350 sxs cement 40#, N-80 3,661' 4,122' 8rd LTC / 8.835" 23#, N-80 Surface 1,667' 8rd LTC / 4.670" ' 20#, N-80 1,667' 3,897' 8rd LTC / 4.778" 600 sxs cement (15 stage) 5-1/2" Liner 17#, N-80 3,897' 6,964' 8rd LTC / 4.892" 20#, N-80 6,964' 9,459' 8rd LTC / 4.778" 500 sxs cement (2nd stage) 23#, N-80 9,459' 11,136' 8rd LTC/4.670" Tubing 2-3/8" Production 4.7#, N-80 18.59' 10,306' Butt / 1.995" 2-3/8" Production 4.7#, N-80 10,452' 10,515' Butt / 1.995" 2-3/8" Production 4.7#, N-80 10,515 10,833' EUE 8rd / 1.995" Produc tion String Jewelry Detail # Depth (RKB) Len th ID OD Item 1 18.59' .58' 1.995" Tubin Han er w/ CIW t e H BPV 2 6.25' (+/-) 1.901" 4.25" GLM @ 2,059', 3,124', 4,113' 5,093', 6,048', 6,760', 7,473', 8,127', 8,778', 9,428', 10,113' 2A 7,516' DV Collar 3 10,284' .85' 2.50" 3.75" Baker K Anchor 4 10,285' 7.22' 2.390" 4.375" Baker HP1-AH Packer 5 10,299' .73' 1.875" 2.875" X-Ni le 6 10,305' .67' 1.995" 2.875" Wireline Re-ent 7 10,453' 4.475' 2.688" 4.57" Baker SC-2P Packer 8 10,457' 5.53' 2.995" 3.50" Baker Millout Extension 9 10,476' 4.04' 1.875" 3.10" Slidin Sleeve CMU 10 10,502' .75' 1.875" 3.10" X-Ni le PX Plu set in same on 9/19/96 11 10,510 3.98' 1.995" 4.125" Baker Telesco in Joint 12 10,515' 2.82' 2.441" 2.90" Bowen 150 Overshot w/ Gra le 13 10,530' 3.92' 3.10" Brown HS-16-1 Packer 14 10,600' 13.07' 2-3/8" Camco MM GLM 15 10,643' 3.92' Brown HS-16-1 Packer 16 10,662' 1.47' Otis S Ni le Position 1 17 10,723' 13.0' 2-3/8" Camco MM GLM 18 10,766' .89' Camco D Ni le 19 10,768' Baker Model F Packer 20 10833' Tubin Tail with Muleshoe Perforation Data ZONE TOP BTM Shot Condition G-2 10,388' 10,423' 6s f Re erfed 2/28/09 10,450' 10,450' Isolated b PX lu -Active 10,470' 10,495' Isolated b PX lu -Active 10,509' 10,525' Isolated b PX lu -Active H l k 10,542' 10,630' Isolated b PX lu -Active em oc 10,655' 10,713' Isolated b PX lu -Active 10,721' 10,764' Isolated b PX lu -Active 10,779' 10,825' Isolated b PX lu -Active 10,833' 10,875' Isolated b PX lu -Active Fish Detail: • Left Temp Sub & Spinner, tagged @ 10,708' on 9/14/87 SCU 332-04 Actual Well Schematic 3-2-09.doc Updated by CVK Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 332-04 SOLDOTNA CK UNIT 332-04 FEDA028997 5013310107 QA5249 18.00 _ - - --- - --__ Jobs _ _ Primary Job Type Job Category Objective Actual Start Date Actual End Date Perforation - Re-Perforation Well Reperf G-2 2/25/2009 Services Primary Wellbore Affected Wellbore UWI Well Permit Number SCU 332-04 5013310107-00 1600190 _ -- -- Daily Operations _ __ 2/25/2009.05:30 - 2/25/2009 16:30 Operations Summary Perform "brush & flush" to prep well for perforating. Pumped 45 bbl hot oil down flow lines and tubing. RIH w/ 1.870" GR and tagged fill at 10,434' SLM. Drift tubin with 20' x 1.75" dumm uns and to ed fill at 10,434' SLM. -- _ - "2128/2009 00:00. - 3/1/2009 OOt00 ___ Operations Summary RU Eline. RIH tie in and tag fill at 10,448' RKB. Reperf Bench G-2 w/ 1.56" Powerjet hollow carrier gun from 10,388'-10,423' RKB. Rig down Eline. Turn well over to production. e e Chevron Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com March 16, 2006 Steve McMains AOGCC 333 W. ¡th Avenue, Ste. 100 Anchorage, Alaska 99501 ¡\!\/),R 1 :6 ~& Re: Outstanding Sundries Dear Mr. McMains, We have conducted an internal audit of regulatory filings for 2003 and 2004. As a result, several projects were found to have outstanding sundries. We have researched the work and have prepared the sundries to close out the projects left uncompleted. The list of projects includes the following: 2003 Grayling, G-12RD3, Reperforate Grayling, G-24, Reperforate Monopod, A-15RD2, Perforate Steelhead, M-01, Repair Casing Patch Steel head, M-05, Perforate Swanson River, SCU 32-04, Reperforate (3 Sundries) .../ Swanson River, SRU 12-15, Recomplete Swanson River, SRU 32A-33, Reperforate \\,O~ 0 \q 2004 Happy Valley, HV-A02, Coil Tubing Clean Out In order to assure that we do not have any such gaps in the future, we have implemented a database to track all drilling related AOGCC filling requirements. Please contact me directly at 263-7657 if you have any questions about these filings. Sincerely, Z::¿ ~. :} ~; Timothy C. Brandenburg Drilling Manager Attachments Cc: Well Files TB:sk Union Oil Company of California I A Chevron Company http://www.chevron.com STATE OF ALASKA ALAS.IL AND GAS CONSERVATION COMM4toN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U StimulateU Other ~ Reperforate Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D Change Approved Program D Operat. Shutdown 0 Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 160-019 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic D Service D 6. API Number: 50-133-10107-00 7. KB Elevation (ft): 9. Well Name and Number: 18.59' SCU 32-04 8. Property Designation: 10. Field/Pool(s): Soldotna Creek Unit Swanson River Fieldl Hemlock, G-zone 11. Present Well Condition Summary: Total Depth measured 11,136' feet Plugs (measured) 11,015' true vertical 10,951' feet Junk (measured) nla Effective Depth measured 11,015' feet true vertical 10,834' feet Casing Length Size MD TVD Burst Collapse Structural 30 . 22" 30 30' Conductor Surface 1 ,469' .13-3/8" 1 ,469' 1 ,469' 2,730 psi 1 ,130 psi Intermediate 4,122' 9-5/8" 4,122' 4,121' 5,750 psi 3,090 psi Production 11,136' 5-1/2" 1,136' 10,951' 7,740 psi 6,280 psi Liner Perforation depth: Measured depth: 10,388' to 10,875' True Vertical depth: 10,225' to 10,698' Tubing: (size, grade, and measured depth) 2-3/8",4.7#, N-80 @ 10,833' Packers and SSSV (type and measured depth) Packers: Baker HP1-AH @ 10,285'; Baker SC-2P @ 10,460'; Brown HS-16-1 @ 10,530', 10,643'; Baker Model F @ 10,768' 12. Stimulation or cement squeeze summary: Intervals treated (measured): nla Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 56 131 0 700 110 Subsequent to operation: 139 118 0 760 145 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run ExploratoryD Development [] Service D Daily Report of Well Operations X 16. Well Status after proposed work: Oil 0 GasD WAG D GINJ 0 WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or NIA if C.O. Exempt: nla Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature '7 -Zc/5 Phone 907-276-7600 Date ~-/b-Db ~, Form 1 0-404 Re~sed 04/2004 µ'" .cfIJÐMi BFL MAR 1 '1 2006~, Submit Original Only ') Well Name: SCU 32-04 Operator: Unocal Alaska Field: Swanson River Unit: Soldotna Creek API: 33-10101-00 Permit: 160-019 Well Status: RKB: 59' TD/TVD: ,136'/10,951' PBTD/PBTVD: 1,015'/10,834' I etail ~~ Size .Grade rype Top (FT) 22" tructural 0.00 13-3/8" ;5# J-55 Surface ;¡ 9-518" 43.5# 80 Intermediate 186.00 186.00 9-5/8" 47# -80 Intermediate 3,661.00 3,475.00 9-5/8" 40# -80 Intermediate 3,661.00 4:122:00r 461.00 5-1/2" 23# N-80 Production 0.00 1,667.00 " N-80 i Production 1,667.00 2,230.00 N-80 uction 3,89~ 6,964.00 3,067,00 N-80 uction 6,964. 9,459,00 2,495.00 5-1/2" 123# N-80 Production 9,459.001 11,136.00 1,677.00 Tubing Detail Size Wt Grade Type Top (FT) Btm (FT) Length (FT) 2-3/8" 4,7# N-80 Buttress 18.591 10,306.001 10,287.41 2-3/8" 4.7# N-80 Buttress ~ 63.00 2-3/8" 4.7# N-80 Buttress 10,833.00 318.00 ~ ! Type Depth Type Depth 1. Tbg Hgr w/CIW type H BPV 18.59' 10. Bowen 150 Overshot w/Grapple 10,5 2. GLMs: 2,059'; 3,124'; 4,113'; 5,093'; 6,048'; 6,760'; 11. Brown HS-16-1 Packer 10,530' 7,473'; 8,127'; 8,778'; 9,428'; 10,113' 12.2-3/8" Camco MMGLM 10,600' ~ch" 1 0,284' 13. Brown HS-16-1 Packer 10,643' -AH Packer 1 10,662' (ID = 1.875") 10,299 15. 2-3/8" Cameo MM GLM I Re-entry 10,305' 16. Camco D Nipple 17. Baker SC-2P Packer 10,460 17. Baker Model F Packer 8. Sliding Sleeve eMU 10,476'118. Tubing tail with muleshoe 10 10,502'1 ail SPF Zone Status Top (FT) 8tm (FT) Length (FT) 3 6 G-2 Active 10,388.00 10,393.00 5,00 3 6 G-2 Active 10,393.00 10,403.00 10.00 6 G-2 Active 10,403.00 10,413.00 10.00 Mar-03 6 G-2 Active 10,413.00 10,423.00 10.00 WSO 10,450.0C 10,450.00 0.00 Hemlock Active 10,470.00 10,495.00 25.00 Hemlock Active 10,509.00 10,525.00 16.00 Hemlock Active 10,542.00 10,630.00 88.00 Hemlock Active 10,655.00 10,713.001 58.00 Hemlock Active 10,721.00 10,764.00 43,00 ~Ck Active 10,779.00 10,825.00 46.00 Hemlock Active 10,833.00 10,875.00 42.00 .. 3/14/03 e e .... Prior Day 3/14/03: Rigged up but did not raise lubricator because of wind. Monitored wind until 03:00 then SDFN. 3/15/03 Stabbed on lubricator and shut in well. PJSM. Pressure tested to 500/2,200 per program. RIH with gun # 1. Tied in with Schlumberger log 10/2/96. Bled tubing pressure from 700 to 150 #. Fired gun # 1. Shot 10,413 - 10,423 (10 feet). Saw weight Loss. Logged up and POOH to reload. RIH with gun # 2. Tied in with line marker and log. Fired gun # 2. Shot 10,403 -10,413 (10 feet). Saw weight Loss. Logged up and POOH. TP @ 200 #. RIH with gun # 3. Tied in with line marker and log. Fired gun # 3. Shot 10,393 - 10,403 (10 feet). Saw weight Loss. Logged up and POOH. TP @ 200 #. RIH with gun # 4. Tied in with line marker and log. Fired gun # 4. Shot 10,388 - 10,393 (5 feet). Saw weight Loss. Logged up and POOH. TP @ 250 #. POOH and closed swab. Rigged down. SCU 32-04 (160138) morning report summary, CONFIDENTIAL: last revised 10/20/2005, Page 1. STATE OF ALASKA a ALAS.IL AND GAS CONSERVATION COMM_ON REPORT OF SUNDRY WELL OPERATIONS 1 . Operations Abandon Repair Well Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations Perforate New Pool D Perforate D 4. Current Well Class: Development [] Stratigraphic D Stimulate Other ..I WaiverD Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 160-019 ServiceD 6. API Number: 50-133-10107-00 9. Well Name and Number: SCU 32-04 10. Field/Pool(s): Swanson River Fieldl Hemlock, G-zone Reperforate 7. KB Elevation (ft): 18.59' 8. Property Designation: Soldotna Creek Unit 11. Present Well Condition Summary: Total Depth measured 11,136' feet true vertical 10,951' feet Effective Depth measured 11,015' feet true vertical 10,834' feet Casing Length Size MD Structural 30 22" 30 Conductor Surface 1 ,469' 13-3/8" 1 ,469' Intermediate 4,122' 9-5/8" 4,122' Production 11,136' 5-1/2" 1,136' Liner Plugs (measured) 11,015' Junk (measured) n/a TVD Burst Collapse 30' 1 ,469' 2,730 psi .1,130 psi 4,121' 5,750 psi 3,090 psi 10,951' 7,740 psi 6,280 psi Perforation depth: Measured depth: 10,388' to 10,875' True Vertical depth: 10,225' to 10,698' Tubing: (size, grade, and measured depth) 2-3/8",4.7#, N-80 @ 10,833' Packers and SSSV (type and measured depth) Packers: Baker HP1-AH @ 10,285'; Baker SC-2P @ 10,460'; Brown HS-16-1 @ 10,530', 10,643'; Baker Model F @ 10,768' 12. Stimulation or cement squeeze summary: Intervals treated (measured): nla Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 40 0 740 70 1 900 15. Well Class after proposed work: ExploratoryD Development [] 16. Well Status after proposed work: Oil[] Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 57 217 Tubing Pressure 140 135 Service D x WDSPL D Sundry Number or N/A if C.O. Exempt: nla GINJ D WINJ D Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Signature Title Drilling Manager Form 10-404 Revised 04/2004 AFE 16153 Date 3-/~ -Ob Submit Original Only 11/13/03 e e MIRU. PJSM. Pressure test to 2,350 (OK). RIH with gun #1 (10 foot), hydraulic jars, and CCL. Tied in with Schl GRlCCL 10-3-96. TP @ 250-300 psi. Fired gun. Perforated 10,413-10,423 (10 feet) with 1.56 HC. Logged up and POOH. No problem. RIH with gun #2 (10 foot), hydraulic jars, and CCL. Tied in with jewelry as before. Fired gun. Perforated 10,403-10,413 (10 feet) with 1.56 HC. Logged up and POOH. Lots paraffin on gun. RIH with gun #3 (10 foot), hydraulic jars, and CCL. Tied in with jewelry. Fired gun. Perforated 10,393-10,403 (10 feet) with 1.56 HC. Logged up and POOH. Lots paraffin on gun. RIH with gun #4 (5 feet of shots), hydraulic jars, and CCL. Tied in. TP@ 250-300 psi. Fired gun. Perforated 10,388-10,393 (5 feet) with 1.56 HC. Logged up and POOH. RD. TP 250-300 psi. SDFN. SCU 32-04 (161532) morning report summary, CONFIDENTIAL: last revised 10/21/2005, Page 1. '" Well Name: SCU 32-04 Oper¡;¡tor: Unocal Alaska Field: Swanson River Unit: Soldotna Creek API: 50-133-10107-00 Permit: 160-019 WeUStatus: well RKB: 18.59' TD/TVD: 11,136'/10,951' PBTD/PBTVD: 11,015'/10,834' Detail Size Wt ~"," Top (FT) Btm (FT) Length(FT) ~ 0.00 ~ .5# J-55 Surface 0.00 'i 9-5/8" N-80 Intermediate 0.00 186.00 9-5/8" -80 186.00 3, 9-5/8" -80 3,661.00 4,122.00 461.00 5-1/2" -80 0.00 1,667.00 1,667.00 5-112" 1,667.00 3,897.00 2,230.00 5-1/2" 7# N-80 Production 3,897.00 6,964.00 3,067.00 5-1/2" 0# N-80 Production 6,964.00 9,459.00 2,495.00 5-1/2" 3# N-80 Production 9,459.00 11,136.00 1,677.00 Tubing Detail Size Wt Grade Type Top (FT) 8tm (FT) Length (FT) 2-3/8" 4.7# N-80 Buttress 18.59 10,306.00 10,287.41 2-3/8" 4.7# N-80 Buttress 10,452.00 10,515.00 63.00 2-3f8" 4.7# N-80 Buttress 10,515.00 10,833.00 318.00 Jewelry Detail Type Depth Type Depth · Tbg Hgr w/CIW type H BPV 18.59' 10. Bowen 150 Overshot w/Grapple I 2. GLMs: 2,059'; 3,124'; 4,113'; 5,093'; 6,048'; 6,760'; 11. Brown HS-16-1 Packer 10, 7,473'; 8,127'; 8,778'; 9,428'; 10,113' 12.2-3/8" Cameo MM GLM · Baker K Anchor 10,284 13. Brown HS-16-1 Packer · Baker HP1-AH Packer 10, 14. Otis S Nipple Position 1 10,662' · X-Nipple (ID = 1.875") 10, 5. 2-3/8" Camco MM GLM 10,723' 6. Wireline Re-entry 10,305' 16. Camco D Nipple 10,766' 1. Baker SC"2P Packer 10,460' 17. Baker Model F Packer 10,768' 8. Sliding Sleeve CMU 10,476' 18. Tubing tail with muleshoe 10,833' ~1.875") 10,502' Detail Date SPF Zone Status Top (FT) Btm (FT) Length (FT) Nov-03 6 G-2 Active 10,388.00 10,393.00 5. Nov-03 6 G-2 Active 10,393.00 10,403.00 10. Nov-03 6 G-2 Active 10,403.00 10,413.00 10. Nov-03 6 G-2 Active 10,413.00 10,423.001 10. WSO 10,450.00 10,450.00 O. ctive 10,470.00 10,495.00 25.00 ctive 10,509.00 10,525.00 16.00 ctive 10,630.00 88.00 10 ctive 10,655.00 10,713.00 58.00 10,721.00 10,764.00 43.00 10 ctive 10,779.00 10,825.00 46.00 ctive 10,833.00 10,875.00 42.00 ¡Last Revised: 110/21/2005 I Revised By: IDED A STATE OF ALASKA ALASWOIL AND GAS CONSERVATION COM4oN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U StimulateU Other ~ Reperforate Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of Califomia 4. Current Well Class: 5. Permit to Drill Number: Name: Development [] ExploratoryD 160-019 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic D Service D 6. API Number: 50-133-10107-00 7. KB Elevation (ft): 9. Well Name and Number: 18.59' SCU 32-04 8. Property Designation: 10. Field/Pool(s): Soldotna Creek Unit Swanson River Field/ Hemlock, G-zone 11. Present Well Condition Summary: Total Depth measured 11 ,136' feet Plugs (measured) 11,015' true vertical 10,951' feet Junk (measured) nla Effective Depth measured 11,015' feet true vertical 10,834' feet Casing Length Size MD TVD Burst Collapse Structural 30 22" 30 30' Conductor Surface 1 ,469' 13-3/8" 1 ,469' . 1 ,469' 2,730 psi 1 ,130 psi Intermediate 4,122' 9-5/8" 4,122' 4,121' 5,750 psi 3,090 psi Production 11,136' 5-1/2" 1,136' 10,951' 7,740 psi 6,280 psi Liner Perforation depth: Measured depth: 10,388' to 10,875' True Vertical depth: 10,225' to 10,698' ." Tubing: (size, grade, and measured depth) 2-3/8",4.7#, N-80 @ 10,833' Packers and SSSV (type and measured depth) Packers: Baker HP1-AH @ 10,285'; Baker SC-2P @ 10,460'; Brown HS-16-1 @ 10,530', 10,643'; Baker Model F @ 10,768' 12. Stimulation or cement squeeze summary: Intervals treated (measured): nla Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 124 8 0 780 170 Subsequent to operation: 126 11 0 800 140 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run ExploratoryD Development [] Service D Daily Report of Well Operations X 16. Well Status after proposed work: Oil[] Gas D WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: n/a Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature 7-~~ ~ Phone 907-276-7600 . ''1 ~:~~~ Date "5 - /6 --é:JG ~ Form 1 0-404 ~ised 04/2004 ~ , .... 0, ¡'1M" ¡, I.UVU \ AFE 163264 Submit Original Only 11/26/04 e e Pollard out RIH with scratcher cut paraffin, while pumping oil from 6' to 125'. RIH W/1.6" GR, cut paraffin from 220' to 880', tools fell to 1100', cut paraffin to 1550', falling free to 2500'. POOH RIH WI 1.75 GRcut paraffin from 400' to 850', tag fill @ 10443 POOH. RIH WI 20' long 1 11/16" dummy gun, trouble falling from 700' to 900', noticed FL @ 2350', drifted to 10440'. POOH and RD 11/27/04 Conduct PJSM, Pollard RU and test lubricator. MU program survey tool string. RIH WI survey tools, for flowing gas lift survey making stops as per program. POOH confirm good data. RD fuel and store equipment 11/28/04 Conduct PJSM with SWS and all personnel involved; go over Unocal explosives and perforation checklist. Gun run #1, RIH WI 20' long HSD-WL-1.56", 1606 PJ, HMX, 6spf, correlate with SWS GR-CCL 10-03-96, and completion log 11-13-03. Perforate from 10403 to 10423' (CCL 3.2' on depth @10399.8') guns fired at 13:00 hrs. POOH all guns fired. Gun run #2RIH WI 15'long, HSD-WL-1.56in, 1606 PJ, HMX, 6SPF correlate with SWS GR- CCL 10-03-96, and completion log 11-13-03. Perforate from 1 0388' to 10403' (CCL 8.2' on depth @ 10379.8) guns fired at 14:05 HRS. POOH all guns fired. RD SWS, Turn well over to production SCU 32-04 (AFE 163264) morning report summary, CONFIDENTIAL: last revised 10/21/2005, Page 1. '" Well Name: SCU32-04 perator: Unocal Alaska Field: Swanson River Unit: Soldotna Creek API: 50-133-10101-00 Permit: Well Status: Oil well RKB: 11,136'/10,951' PBTD/PBTVD: 834' ~ G<od. Type Top (FT) Btm (FT) Length (FT) Structural 0.00 ;¡; 30.00 ~ Surface 0.00 1,469.00 N-80 oj 3001 186.00 5/8" N-80 Intermediate 186. 3,475.00 9-5/8" 40# N-80 Intermediate 3,661.00 4,122.00 461.00 5-1/2" 123# N-80 Production 0.00 1,667.00 1,667.00 U N-80 Production 1,667.00 3,897.00 2,230.00 5-1/2" N-80 Production Ii 6,964.00 3,067.00 5-1/2" N-80 Production 9,459.00 2,495.00 N-80 Production 9,459. 11,136.00 1,677.00 Size Wt Grade Type Top (FT) Btm (FT) length (FT) 2-3/8" 4.7# N-80 Buttress 18.59 10,306.00 10,287.41 2-3/8" 4.7# N-80 Buttress 10,452.00 10,515.00 63.00 2-3/8" 4.7# N-80 Buttress 10,515.00 10,833.00 318.00 Jewelry Detail Type Depth Type Depth 1. Tbg Hgr w/CiW type H BPV 18.59' 10. Bqwen 150 Overshot w/Grapple 10,515' 2. GLMs: 2,059'; 3,124'; 4,113'; 5,093'; 6,048'; 6,760'; 11. Brown HS-16-1 Packer 10,530' 7,473'; 8,127'; 8,778'; 9,428'; 10,113' 12. 2-3/8" Camco MM GLM 10,600' ~ 10,284' 13. Brown HS-16-1 Packer 10,643' 10,285' 14. Otis S Nipple Position 1 10,662' 5. X-Nipple (iD = 1.875") 10,299' 15. 2-3/8" Cameo MM GLM 10,723' 6. Wireline Re-entry 10,305' 16. Camcop Nipple 10,766' 1. Baker SC-2P Packer 10,460' 17. Baker Model F Packer 10,768' 8. Sliding Sleeve CMU 10,476' 18. Tubing tail with muleshoe 1 9. X·Nipple (10 1.875") 10,502' Perforation Detail Date SPF Zone Status Top (FT) Btm (FT) Lrmgth (FT) Nov-04 6 I G-2 Active 10,388.00 10,403.00 15.00 Nov-04 6 ~ Active 10,403.00 10,423.00 20.00 SO Î 10,450.00 0,00 k Active 10,495.00 25.00 1 Hemlock Active 10,509. II 16.00 i Hemlock Active 10,630. 88.00 58.00 Hemlock Active 10,721. 10 43.00 Hemlock Active 10,779.001 10,825.00 46.00 Hemlock Active 10,833.001 10,875.001 42.00 ') ) Unocal Alaska 909 W. 9th Avenue Anchorage. AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com UNOCAL@ Debra Oudean G & G Technician Date: June 15, 2005 To: AOGCC Helen Warman 333 W. ¡th Ave. Ste#100 Anchorage, AK 99501 . - h.- r trc::r'''. SEO 1 C) ?OO¡- SC,.t;t\H\!1r,;,r.) \. .::. r .1. (..) ~- ,) ~~~'i~'JIII.61! ,'il\:";",.:', "r" ":,:Io-{'\"":;' ':·API··' NUMBER INCH 3/17/2005 3920-4063 INTERVAL RUN B. NOtES· LOGGED # LINE LAS, PDS, DLlS 1 pds \SI~U"'·-·"""~'·-~3'ëhlu~b~·~gër··'1·94-0840 501331014101 PLUG SETTING RECORD 132A-15 WEATHERFORD RETRIEVABLE I PLUG . --.............; ·scÜ--"--"-šctiiü·mberger: . 16¡}Ö'210" 'ŠÕ'1331-Õ104ÕÕ-'PRESSÜÃETEMP 'sÙÃvË"Ÿ--"- ...... .---. 6/8/2005 9900-10185 1 dlis:las, pds I 314-04 COMPLETION RECORD 2.25 HSD I I POWERJETS fscu šC"hlümberáer- ·199·~54Õ"5Õ133·1Õ125Ò1- pCUGSETTIÑ"G-FiECÕ"R.oiš-;;---....----------4ï3Ò/2ÕÕŠ.-.1"0530~1()675-'-'1-'-'---'-'1" pds -¡ ¡'21A-09 MAGNA RANGE BRIDGE PLUG ¡ CEMENT DUMP BAILER I ¡scú·····"· Sëhlü';n-berger' -16õ-~õ2·1·õ--·Š01··331ö1·õ¡õö·ABÃ·Ñ"[)OÑME-NT..ÃEëoÃD"J1IÑ¡¿-..-..-··--·-··..- -.. -5'/30ï2õõ'51õ185~'1Ö192'-'" '1---------..- ···1·PdŠ--"---·--·-·---i 1314-04 BASKET/GUAGE RING CEMENT j \ RETAINER ! rsctT--"'" 'sèhlümberge~-1--74=Õ540- ŠÕ1331õ"1'10Õ-1- ..COMPÜ~TION·ÃEëÒÃD2-HSD·--..--·· .------. -·6ì1-1/2õõ5·'221-š:2~!2~ï-·--·1..--..·- ·------1· ..pds--------·---·¡ \43A-04 POWERJETS EZ DRILL SQUEEZE i PACKER ! r:::- -.--- .---------- ---.-...-.-.-.....-.-...--- .----.--..----.--.-.-.---....---- -. .------.- -.--.-.-. _______._.___.._n__.. .---..-... ¡SCU Schlumberger 199-0540 501331012501 COMPLETION RECORD 2.5 HSD 5 INCH 5/4/2005 10050-10450 1 1 pds \ '¡21A-09 POWERJET 6 SPF 60DEGREE ¡ PHASING --.J ~.šëu- ISchlunibë~er[160-:Ö190-[5Ò1331 0107ÕO ·¡PERFOÃÃ TING-RECOÃO 1.56 -HSDlS'IÑCH'''r'-st1i2005\1 0240-1 0430 -r1---r"1[pdS I !332-04 . I I POWERJET GUNS . I Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received By: ~ ()/JJ Date: /À..1f1-À.cN l- ~/&(]- OlC( hi '"l " STATE OF ALASKA ALA... lOlL AND GAS CONSERVATION COM\,. .;~ION REPORT OF SUNDRY WELL OPERATIONS REC·''I¡.E....&\' I~:: , ~~~~. ' .::~ S ;1 C JUN {) 6 Z005 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool D Perforate 0 4. Current Well Class: Development 0 Stratigraphic D tU~sk~ Oil & G~~~ Crms" r:n~'nmi~~¡l'I¡¡ Stimulate U Other UA Waiver D Time Extension DG-dlt;~Jr~~~ Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 1600190 Service D 6. API Number: 50-133-1010700 9. Well Name and Number: SCU 332-04 10. Field/Pool(s): SRF/G-Zone 7. KB Elevation (ft): 18.59' RKB to tubing Hanger 8. Property Designation: Soldotna Creek Unit 11. Present Well Condition Summary: Casing Structural Conductor Surface Intermediate Production Liner measured 11 ,136' feet true vertical 10,951' feet measured 10,452' feet true vertical 10,287' feet Length Size MD 30' 22' 30' 1 ,469' 13-3/8" 1 ,469' 4,122' 9-5/8" 4,122' 11,136' 5-1/2" 11,136' Plugs (measured) Junk (measured) 10,502' Total Depth Effective Depth TVD Burst Collapse 30' 1 ,469' 2,730 psi 1,130 psi 4,121' 5,750 psi 3,090 psi 10,951' 7,740 psi 6,280 psi SCANNED JUN 1 4 2005 Perforation depth: Measured depth: 10,388 to 10,423' True Vertical depth: 10,225 to 10,259' Tubing: (size, grade, and measured depth) 2-3/8",4.7#, N-80 @ 10,833 Packers and SSSV (type and measured depth) 10,285' Baker HP1-AH Packer; 10,460' Baker SC-2P Packer; 10,530' Brown HS-16-1 Packer; 10,643' Brown HS-16-1 Packer; 10,768' Baker Model F Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: n/a 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 620 2 0 800 15. Well Class after proposed work: Exploratory n Development rJl 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 93 119 Tubing Pressure 110 160 Service n x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: n/a Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg ... Signature~ c/ff Title Drilling Manager Phone 907-276-7600 Date ?; -(~J -- L.'0 S l,r~p,¡0ìN" I!.\L i ¡: ,'\! r"l;l ¡, _~, ''"'' ~ . . \...,) Î a ~ \ ReOMS SF' L ,JUN 0 " 2005 Form 10-404 Revised 04/2004 Submit Original Only f,. P: UNOCALe API: 50-133-1010700 AOGCC: 1600190 RKB: 18.59' Jewelry 1. 18.59' Tubing hanger w/CIW Type H BPV. 2. GLMs at 2,059'; 3,134'; 4,113'; 5,093'; 6,048'; 6,760'; 7,473'; 8,127'; 8,778'; 9,428'; 10,113'. 3. 10,284 Baker K Anchor 4. 10,285' Baker HP1-AH Packer 5. 10,299' X Nipple 6. 1 0,305' Wireline Re-entry 7. 10,460' Baker SC-2P Packer 8. 1 0,452' Packer Retrieving Extension 9. 10,476' Sliding Sleeve CMU 10.10,502' X Nipple w/plug 11. 10,510' Baker Telescoping Joint 12. 10,515' Bowen Series 150 Overshot W/Grapple 13. 10,530' Brown HS-16-1 Packer 14. 10,600' 2-3/8" Camco MM GLM 15. 10,643' Brown HS-16-1 Packer 16. 10,662' Otis S Nipple Position 1 17.10,723' 2-3/8" Camco MM GLM 18.10,766' Camco D Nipple 19. 10,767' Stop Sub for Seal Assy. 20. 10,768' Baker Model F Packer 21. 10,833' Tubing Tail with Mule Shoe As Completed 5/2/05 ) 2 ... ..... ..... .... :8 g 3 ~ 4 5 ~ 6 ::8 g 7,8,9 -- 10 - 11 12 I == l 13 ::8 g 15 16 17 18 19 20 ::8 g 21 14 ~ ~ PBTD = 10,452' TD = 11,136' ) Well Name: SCU 332-04 Field: Swanson River State: Alaska Conductor: 22" @ 30' Surface Casinq: 13-3/8",54.4#, J-55 @ 1,469' Intermediate Casing: 9-5/8" 43.5#, N-80 @ 186' 9-5/8" 47#, N-80 @ 186 to 3,661' 9-5/8" 40#, N-80 @ 3,661 to 4,122' Production Casing 5-112",23#, N-80 @ 1,667' 5-1/2",20#, N-80 @ 1,667 to 3,897" 5-1/2", 17#, N-80 @ 3,897 to 6,964' 5-1/2",20# N-80 @ 6,964 to 9,459' 5-1/2",23#, N-80 @ 9,459 to 11,136' Production Tubinq: 2-3/8",4.7#, N-80 @ 10,833' Perfs: 10,388 to 10,423, G-2, 4 SPF Isolated: 10,470 to 10,495', Hemlock 10,779 to 10,825', Hemlock 10,509 to 10,525', Hemlock 10,542 to 10,630', Hemlock 10,665 to 10,713', Hemlock 10,721 to 10,764', Hemlock 10,833 to 10,875', Hemlock 10,450', WSO Updated by: DED I~= ..~.. -.-r--- ~, ",LII.f Well Name Flela Name SCU 32-04 SWANSON 'Primary Job Type Perforating '-tr¡i-. ~I ~~ r, Lease/Serial FEDA028997 I Primary Wellbore Affected Main Hole I 1 , ~I '~ lOng KB Elev (ftKB¡ I Water Deptn 1,1t) 180.0 Daily Operations 4/29/200500:00 - 4/30/2005 00:00 Operations Summary PJSM. RU wireline. RIH with 1.80" GR tagged at 211'. RIH with brush while pumping diesel. Continue to spud on obstruction at 216' POOH. RD wireline. 4/30/200500:00·5/1/200500:00 Operations Summary PJSM, RU wireline. RIH wi brush while pumping hot diesel. RIH w/1.8" GR to 10,456'. Tagged. POOH. Fluid level at 2800', RIH w/1-11/16"x 20' dummy gun down to 10,456'RKB. POOH. RD wireline. 5/1/2005 00 :00 . 5/2/2005 00:00 Operations Summary PJSM. RU schlumberger wireline. Arm 1.56"x 20', HC, 6spf, 60 deg phase perf gun. RIH wi perf gun, tie in wi Schlum. GRICCL log (10/3/96). Shoot 10,388' - 10,403. POOH. RD Schlumberger, turn well over to production. l l ) ) /Go -o/? /9tf- {Ylf Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocaI.com UNOCALe Debra Oudean G & G Technician Date: March 10,2005 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 SRU 32A-15 & SCU 32-04 j, š;u~;~ti:.-¡ci~PLET:I~0R~~ÕR~~~~~¿~~~TS-·~:::_:_---~-- ~~~:r1~1~4¡~~~f~~~--~~~~i ~-~¡~~ ,¿ fšRÛ32A-15 lCOMPLET'ION'ÄÊCOÁD 2 HSD PÖWéRJETŠ·-~'-'~~··""~ , '¡'SINCH r 1/241200~15375-56sS '1 1 rr1 /rSRU 32A-15 g~~~~~~~~;~CORD 2 HSD POWERJETS SET CIBP/F As-Is INCH 1112/2712004 5535-5760 -r-' 1 11 ( I~RU 32A-15 i ~~~~~~~ON RECORD 2 HSD POWERJETS SET FAS DRILL 5 INCH ! 12/29/2004: 4800-5230 1 1: 1, ( ."'....._...............................................~..........................................._......................._...~........._..........._................,.....,....._...._....,.................................,..,............n.............................,...;..............................~...................._............_.....;............._..........................._......._................._.................;.....,...w........................, /SRU 32A-15 COMPLETION RECORD 2 HSD POWERJETS SET FAS DRILL 51NCH 12/31/2004 3270-3640 1 1 1 RETAINER ~... .~:".. .~_¥~_~_. ~.~........... ..~. . ..' ..... ...~ .. .... .'~ ~...._." .._... ..."........ _. ....... ..~.._.:."..~ .._ .._....~._ ..._ ~., ..,," ......_.,,_ . ~." ~ ..... .~.. .....". . .... ." . .... ......... ~~....:.. ..__..___..~._....... .~....... .__." ......... .... _... .. . .. .... ._.._1........ ...... BC.ANNE£: JUN 1 6 2005 Please aCknoWI~~t b; s-kt:n:a::PY of thi~);j:~ to (907) 263-7828_ Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCALi) """'-Alaska Debra A Oudean G & G Technician February 26, 2004 DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7tn Ave, Suite 100 909 W. 9th Avenue Anchorage, AK 99501-3539 Anchorage, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: ',1t~~~':;1;f:';(~iil;i!,;}B;1r¡~~~~!i~~i~2i:H;;,!:~;t~': ,,~~" M~~~~t $,~~%~1;~~I~EiF,ii~;; t~ö,:rl )(!f) - 019 SCU 332-4 COMPLETION RECORD SAFE 1.56 HSD PJ 5 INCH 11/13/2003 10175-10450 1 1 1j 1dJ...)L/~ J{d)-~~~~~~~~~=r~~.~¥T=~F~r~~~~Z~ - )6","-RÛ-'21-3:;'õ"-I'"" ëor;Xp"LETioÑ-RËcÕRD-2'I~SÕ'6SP.FPOWËÄJET60-'-1" 5-ÎN6H-'--::"I-'-ä/23/2ÕÕ3,,'13õ9o~361'~ï""'--'-'-'-,I"----'-"-'1~,I'-"---1",',I""--"".-'1, J!!J LI L .- ~,-) 1<Õil ¡DEGREE PHASED [I : ¡ :'1: (/~/' I ' 138 - 15 T rSRÜ-242~6~.'fêõMPLETiõ"ÑR-EëõÃ-ö2':5-HsD.6šPFPJ"-'-"'''''-''-'-'--"'l5ï'ÑëH-'1-'-äi23ï2äõ3l3.5'9õ:421'1.'"~'"''''"""1'''-'''-''-'-'''''''1T--''--1r~.''.;.' J a.l.fLJ ' } ~~~~111::~~;;~... ~~~:~~~:~~;~~~:~~~~;~~;~;~_::~~]I: :~~~-1~~~~;;:rl;~:~~~5 - pl. -:11 ~J~~ ~~~~ J 9il'O~.SRU 41A-8 , ,GAMMA RAY CCL 1.56 POWER JETS 1606 HMX SINCH 2/12/2004 9740-10590 ._~~~J~4t¡¿ RECEIVED S~A~~ð~eL ¡!\ljJU~ 1 Q) 20o.~ FEB 2 7 2004 i1!aska Oil & Gas Cons. Commision Þ,n_" of this transmittal or FAX to 907 263-7828. Date: ~~~f\\'~ Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harfisonb~unocal.com UNOCAL Beverly Harrison Business Ventures Assistant April 2, 2003 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - SCU 332-4 2'4: ', 9-",; Y.;' ". "'"'"":" '.. ' "' ' '~'' :/~'."::~J.,'~.'.; ~::"-';'., 2,':. : -, .... :.v.: I COMPLETION RECORD 1.56" HSD POWER JET 1606, HMX 5 INCH 3/15/2003 10100-10430 1 501331010700 B-Line COMPLETION RECORD 1.56" HSD POWER JET1606, HMX 5INCH 3/15/2003 10100-10430 1 501331010700 CD COMPLETION RECORD 1.56" HSD POWER JET 1606, HMX 5 INCH 3/15/2003 10100-10430 1 501331010700 Film Please acknowledge receipt by signing and returning one copy of this trar~EC~ tV(.F~63-7828. Date: Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager 12/29/00 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Soldotna Creek unit Well SCU 32-4 APl No. 50-133-10107-00 10-404 Reperforate G-Zone Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the reperforation of the G2 bench in well SCU 32-4. The following intervals were perforated on 12/13/00: Bench Top Bottom Feet G2 10,388 10,423 35 Total: 35 If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, Dan Williamson Drilling Manager RECEIVED jAN 22 2001 Alaska Oil & Gas Cons. Commissior~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION ' 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 1120' FEL, 1040' FNL, Sec. 4, T7N, R9W, SM At top of productive interval 1911' FEL, 2132' FNL, Sec. 4, T7N, R9W, SM At effective depth 2025' FEL, 2289' FNL, Sec. 4, T7N, R9W, SM At total depth 2025' FEL, 2289' FNL, Sec. 4, T7N, R9W, SM 5. Type of Well: Development: X Exploratory: Stratigraphic: Service: 6. Datum elevation (DF or KB) 180' RKB feet 7. Unit or Property name Swanson River Unit 8. Well number ./ scu~.~ ~;;;).--~'/ ~. 9. Permit number/approval number 160-0~9-0 ~, 10. APl number 50-133-10107-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measured 11119 true vertical 10931 feet Plugs (measured) feet Effective depth: measured 11031 true vertical 10843 feet Junk (measured) feet Casing Length Structural 30' Conductor Su dace 1469' Intermediate 4120' Production 11119' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth 22" Yes 30' 30' 13,3/8" 1100 sx 1469' 1469' 9-5/8" 350 sx 4120' 4118' 5-1/2" 1100 sx 11119' 10931' 1~388-1~423~1~47~-1~495~1~5~9-1~525~1~542-1~63~~1~655-1~713~1~721-1~764~1~779-1~825~ 10833-10875 1~226-1~26~~1~3~5-1~33~~1~343-1~359~1~375-1~461~1~485-1~541~1~549-1~591~1~6~5-1~65~~ 1O658-1O698 2-3/8",4.7#,L-80 @ 10306';2-3/8",4.7#,L-80,10452'-10515';2-3/8",4.7#, N-80,10515'-10833' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Baker "HP1-AH" pkr. @ 10285'; Baker "SC-2P" pkr. @ 10460'; Brown "HS-16-1" pkr. @ 10530'; Brown "HS-16-1" pkr. @ 10643'; Baker "F" pkr. @ 10768' R£C£1V£D 14. Intervals treated (measured) JAN 2_2 2.001 Treatment description including volumes used and final pressure A~o~,o rill ~, R~R Cons. Commission Representative Daily Averaqe Production or Injection Data ............. Anchorage OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 161 144 4 850 250 Subsequent to operation 203 214 0 850 200 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: I6. Status of well classification as: Oil: Gas: Suspended: Service: 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: SUBMIT IN 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: X Alter casing: Repair well: Other: 2. Name of Operator 5. TyPe of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 18.59 KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotna Creek Unit 4. Location of well at surface 8. Well number 1120' FEL, 1040' FNL, Sec. 4, T7N, R9W, SM $CU 332-4 At top of productive interval 9. Permit number/approval number 1911' FEL, 2132' FNL, Sec. 4, T7N, R9W, SM 60-0019/96-198 ~ "~ ! ~ At effective depthORIGINAL 10. APl number 2025' FEL, 2289' FNL, Sec. 4, T7N, R9VV, SM 50 133-10170 At total depth 11. Field/Pool 2025' FEL, 2289' FNL, Sec. 4, T7N, R9W, SM Swanson River/Tyonek-Hemlock 12. Present well condition summary Total depth: measured 11119 feet Plugs (measured) 10,502' true vertical 10931 feet \ Effective depth: measured 11031 feet Junk (measured) true vertical 10843 feet Casing Length Size Cemented Measured depth True vertical depth Structural 30' 22" Yes 30' 30' Conductor 1469' 1 469' Surface 1469' 13-3/8" 1100 sx 4120' 4118' Intermediate 4120' 9-5/8" 350 sx Production 11119' 5-1/2" 600 sx 1 st stage 11119' 10931' Liner 500 sx 2nd stage Perforation depth: measured 10470'-10495'; 10509'-10525'; 10542'-10630'; 10665'-10713'; 10721 '-10764'; 10779'-10825'; 10833'-10875'; 10,388'-10,423' true vertical 10294'-10319'; 10333'-10349'; 10366'-10454'; 10749'-10537'; 10545'-10588'; 10603'-10649' 10657'-10699'; 10,212'-10,247' Tubing (size, grade, and measured depth) 2-3/8", 4.7#, L80 10306'; 2-3/8" 4.7# L80 10,452'-10,515' 2-3/8" 4.7# N-80 10,515'-10,833' Packers and SSSV (type and measured depth)RECEIVED Baker "HPI" ~ 10285'; Baker "SC-2P" @ 10452', Brown "HS-16-1" @ 10530' and 10644'; Baker "F" @ 10768' 13. Stimulation or cement squeeze summary OCT 2. 2_ 1996 Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A Alaska 011 & Gas Cons. Commission Anchorage 14. Representative Daily Average Production or Injection Data Oii-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Inject 0 21447 0 1710 4460 Subsequent to operation Produce 282 88 0 975 380 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: x Oil: x Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dale Haines /,,~.~. ~C~ Title: Drilling Manager Date: 10/14/1996 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ' UNOCAL Swanson River Field Well # SCU 332-4 Actual Completion 9/21/96 RKB to TBG Hanger = 18.59' Tree Connection = 2-7/8" 8rd TOC 2835~ ~ CIvlT 6375'- 7516 TOC 8100' TBG lO,515' Leak 10,630-35 Fish :.:+: X DV (~ 7516' 3 4 5 6 8 9 g 11 12 13 14 15 16 17 18 19 20 21 22 PBTD = 11015' TD = 11136' MAX HOLE ANGLE = 17° (~ 7037' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" 0' 30' 13 3/8" 54.5# J-55 8rd STC 0' 1469' 9 5/8" 43.5# N-80 8rd LTC 0' 186' 9 5/8" 47.0# N-80 8rd LTC 186' 3661' 9 5/8" 40.0# N-80 8rd LTC 3661' 4122' 5 1/2" 23.0# N-80 8rd LTC 0' 1667' 5 1/2" 20.0# N-80 8rdLTC 1667' 3897' 5 1/2" 17.0# N-80 8rd LTC 3897' 6964' 5 1/2" 20.0# N-80 8rdLTC 6964' 9459' 5 1/2" 23.0# N-80 8rdLTC 9459' 11136' Tubing: 2-3/8" 4.7# N-80 Buttress 18.59' 10,306' 2-3/8" 4.7# N-80 Buttress 10,452' 10,515' 2 3/8" 4.7# N-80 EUE 8rd 10,515' 10,833' JEWELRY DETAIL NO. Depth Item 1 18.59 2 3 4 5 6 7 8 9 10a 10b 11 12 13 14 15 16 17 18 19 20 Top BTM 10,388' 10,423' 10,470' 10,495' 10,779' 10,825' 10,509' 10,525' 10,542' 10,630' 10,655' 10,713' 10,721' 10,764' 10,833' 10875' *'10,450' 10,284 10,285 10,299 10,305 10,460 10,452 10,476 10.502 10.510 10515 10530 10.600 10.643 10.662 10.723 10 766 10,767 10,768 10,833 Tubing hanger w/CIW Type "H" BPV GLM's at 2059',3124',4113',5093',6048', 6760',7473',8127',8778',9428', 10113 ', Baker "K" Anchor Baker "HP1-AH" Packer "X" Nipple (ID = 1.875") Wireline Re-entry Baker "SC-2P" Packer Packer Retrieving Extension Sliding Sleeve"CMU "X" Nipple (ID = 1.875") Baker Telescoping joint Bowen series 150 Overshot w/grapple Brown "HS- 16-1" Packer 2 3/8" CAMCO "MM" GLM Brown "HS- 16-1" Packer Otis "S" Nipple Position 1 R E¢ E IV E D CAMCO "D" Nipple Stop sub for seal assy OC r ~ ~ 1~}96 Baker Model "F"Packer Tnbing tail w/mnleshoe Alaslm 011 & Oas Cons. Commission Anchorage PERFORATION DATA Zone SPF Date Comments O :~DRILLING\SCHEMATIC\GP\GPP\S C3324A2.DOC G-2 4 Existing Hemlock Existing Hemlock Existing Hemlock Existing Hemlock Existing Hemlock Existing Hemlock Existing Hemlock Existing WSO REVISED' 10/18/96 DRAWN BY: MWD Sheet1 Well Name: Unocal Corporation Well History Report Swanson River-SCU--332-4 Page: I 8/16/96 R/UP CHOKE MANIFOLD & VECO PUMP TRK, DOWELL MIXER, BAKER TANK & BURM/SCU 332-4, TBG = 2725 PSI, PC = 1400 PSI, SC = 90 PSI / BLEED PC F/1300 PSI T/850 PSI @ 100 & MONITOR FOR 30 MINS/BLEED F/850 PSI T/'750 PSI (ALL GAS & OIL @ 750 PSI) / SHUT IN & PUMP 10 BBLS OF LEASE H20 & TEST T/2750 PSI TO 2650 IN 30 MIN / MONITOR WELL SECURE WELL & SHUT DN FOR WELL SECURE WELL & SHUT DN FOR THE NIGHT 8/17/96 CHK PRESSURE ON WELL / TBG = 2750 PSI, PC = 1190 PSI, SC = 90 PSI / MIX 30 BBL SIZED SALT PILL @ 10 PPG W/26.6 PPB BRIDGE SAL, 18.3 PPB PLUG SAL REG & 18.3 PPB PLUG SAL-X / HELD PRE-JOB SAFTY MEETING / PRESURE TEST LINES T/4500 PSI (OK) / BULL HEAD 20 BBLS LEASE H20 AHEAD & 30 BBL LCM PILL @ 2.25 BPM & DISPLACED W/92 BBLS OF LEASE H20 & MOINTOR WELL PRESSURES (ALL ANN REAMAINED) SAME & TBG PRESSURE WENT T/ZERO & STARTED TO BUILD BACK @ 117'; BBLS AWAY SHUT DN TBG PRESSURE @ 1150 PSI/MONITOR PRESSURE 115 PSI/PSI-700 PSI IN 1/2 HR / BLEED TBG T/ZERO (LESS THAN I BBL) / BLEED PC; F/1150 PSI T/600 PSI IN 100 PSI INCERMENTS (OIL BACK @ 600 PSI SHUT IN & LET GAS MIGRATE & MOINTOR) / @ BOWEN CONN, CHK CLEAN & RETEST (OK) / RIH W/1.75" LIB & TAG @ 10712' RKB / POOH & R/DN & SECURE WELL FOR THE NIGHT 8/18/96 CHK PRESURES ON WELL/TBG = VAC, PC = 600 PSI, SC = 90 PSI/BLEED PC F/600 PSi (GAS) T/190 PSI (OIL) & SHUT IN (TO LET GAS MIGRATE) / R/UP SWS & TEST LUB. T/4000 PSI (OK) / RIH W/1-11/16" CCL-GR SET DN @ 10723' RKB WLM & TIE IN & LOG INTERAVEL F/10723' T/10000' / POOH / HELD PRE-JOB SAFTY MEETING / P/UP 1-11/16" HYPERDOME 20J3.2 GRAM 4 SPF 0 DEG 10' PERF GUN W/6' LOADED & CCL / RIH TIE-IN & PLACE GUNS ON DEPTH & PERF TBG & CSG, INTERVAL F/10665' T/10671' / POOH ALL SHOTS FIRED / HELD PRE-JOB SAFTY MEETING / P/UP APRS 1-11/16" CHEM. CUTTER ON SWS / RIH SET DN & HUNG UP (~ 10465' (JARR FREE ~;)500 # OVER) / ATTPT TO WORK THRU (NOGO) / POOH & CHK TOOL (OK) / REMOVE BOW SPRG CENTERLIZERS / RIH W/NO PROBLUMS / TIE-IN & PLACE CUTTER ON DEPTH & SEVER TBG @ 10515' (LOG CUT LOOKS GOOD) POOH & CHK CUTTER (OK) / R/DN SWS & R/UP HOWCO SLICKLINE / BLEED PC F/190 PSI TO ZERO & FILL W/15 BBLS LEASE H20 / FILL TBG W/22 BBLS LEASE H20 / TEST LUB. T/4000 PSI (OK) / RIH W/ CAMCO KICK-OVER TOOL T/GLM @ 10376' (TOOL WILL NOT LOCATE IN GLM) / POOH & DRS LOCATING DOG / RIH & LOCATE GLM & INGUAGE DUMMY VLVE & ATTEMPT T/JARR FREE FOR 2 HR @ 500# OVER LICKS / JARR UP & DN IN ATTEMPT TO SHEER OFF T/ SLIP & CUT LINE OR PULL DUMMY FOR 45 MIN (NOGO) / NO CUTTER ON LOCATION / SECURE WELL & FLAG LINE & SHUT DN FOR THE NIGHT (CUTTER & TBG PUNCH DO (~ 8 AM) 8/19/96 CHK PRESSURES ON WELL / TBG = 150 PSI, PC = 240, SC = 90 PSI / BLEED TBG T/ ZERO (GAS) BLEED PC T/ZERO (GAS) / FILL TBG W/15 BBLS LEASE H20 (TBG ON STRONG VAC) / LOAD & DROP McKINLEY CUTTER & CUT WIRE / POOH & RETRIVE ALL WIRE / CUT 100' WIRE & M/UP NEW TOOL STRING / RIH W/JDC PULLING TOOL & TAG & 90 GRAIN TBG PUNCH W/ONE 1/2" HOLE / RIH & SET DN @ 10348' RKB WLM & PUNCH ONE 1/2" HOLE @ 10345.5' & W/NO NOTICEABLE CHG IN TBG OR ANN PRESS / PUMP 15 BBLS LEASE H20 DN BACK SIDE & PRESSURE UP T/1000 PSI W/NO COMMUNICATION T/TBG, BLEED OFF PRESSURE / POOH & CHK TBG PUNCH FOR FIRE (TBG PUNCH HAD FIRED & LEFT PISTION IN HOLE, PISTION = 1" IN DIM X 1/4" THICK W/3 LITTLE HOLES ON FACE OF PISTION) / R/UP ON TBG & PRESSURE UP 900 PSI & STARTED TO GET COMMUNICATION T/ANN, CONTINUE PUMPING @ PUMP TRK MAX RATE, 2.5 BPM @ 1400 PSI TO STAY AHEAD OF LOSS RATE, PUMP 168 BBLS OF LEASE H20 W/ONLY 102 BBLS OF OIL, GAS & MUD COLORED WATER RETURNS / DN PUMP & RIH W/1.75" L.I.B & TAG @ 10348' RKB WLM ! POOH & GOT GOOD PITCHER OF THE THREE LITTLE HOLES / WAIT ON MAGNET & BAILER RIH W/1.75" MAGNET TAG ~ 10348' POOH (NO REC) / RIH W/1.75" ALLAGATER GRAB (~ MIDNITE 0001 - 0230 HRS: POOH (NO REC) / RIH W/OS & GRAPPLE / TAG FISH (~ 10348' RKB WLM. INGUAGE FISH & SWOLLOW PISTION & GRAB FISHING NECK OF OF FISH #1 / SHEER OFF & POOH & SECURE WELL & PREP TO R/DN SLICKLINE & R/UP BRAIDED LINE IN DAY LIGHT / SHUT DN FOR THE NIGHT 8/20/96 CHK PRESSURES ON WELL / TBG = VAC, PC = 140 PSI, SC = 90 PSI / R/DN SLICKLINE Page 1 Sheet1 Unocal Corporation Well History Report Well Name: Swanson River-SCU--332-4 Page: 2 UNIT & R/UP BRAIDED LINE UNIT W/TOLLOFF BOOM TRK / TEST LUB T/4000 PSI (LEEK, CHK CONNECTION & CLEAN RETEST OK) / RIH W/SB PULLING TOOL & INGUAGE FISH @ 10345' RKB WLM & JARR FREE / POOH & RECOVER TOOL STRING, EQUALIZING PRONG & McKINLY PISTION (BTM OF KICKOVER TOOL CAVED IN) / R/DN BRAIDED LINE & R/UP SLICKLINE UNIT / RIH W/1.80" L.I.B / BLEW HYD VALVE ON SLICKLINE UNIT @ 1500' (ALL OIL CONTAINED IN DRIP PAN, BANDADE LEEK & LIMP OUT OF HOLE) / R/DN SLICKLINE UNIT & R/UP BRAIDED LINE UNIT & RIH W/1.80" L.I.B / SET DN (~ 10494'RKB WLM / HUNG UP, JARR UP HOLE 10' & CAME FREE / POOH L.I.B SHOWED CUT PIPE ON BTM & JUNK MARK FULL LENGTH OF L.I.B ***** JUNK IN HOLE***** / R/DN BRAIDED LINE UNIT / BULL HEAD 30 BBL SIZED SALT PILL @ 10 PPG W/26.6 PPB BRIDGE SAL, 18.3 PPB PLUG SAL REG & 18.3 PPB PLUG SAL-X & DISPLACED W/70 BBLS LEASE H20 / PJDN LINES & SECURE WELL / TBG = VAC, PC = ZERO, SC = 90 PSI **** PUMP HYD OIL INTO PRIMARY/SECONDARY SEAL TEST PORT TO 3000 PSI & TESTED FOR 30 MIN (OK) & LEAVE PRESSURE ON SAME / WELL 323-9 ATTEMPTED TO PUMP GREESE INTO SAME NO TEST, ATTEMPT T/PUMP HYD FLUID INTO (HERD BUBBELING IN WELL HEAD, REENERGI7_E PLASTIC PACKING & RETEST W/HYD OIL 3000 PSI FOR 30 MIN (OK) & LEAVE PRESSURE ON SAME 9/12/96 .... SUSPEND WELL OPERATIONS & WAIT ON RIG & RETURN TO BASE ....... Checked well pressures, tubing on strong vaccum, PC= 20 psi., SC= 90 psi.. Set Cosasco 2 1/2" back pressure valve. Began moving in Nordic rig #5 on turnkey rig move. Laid new 20 mil pit liner and set rig equipment. Raised derrick and continuing to rig up (~ 2400 hrs.. 9/13/96 Nordic completed turnkey rig up. Performed pre-acceptance safety inspection. Corrected sub-standard conditions. Accepted rig (~ 1600 hrs.. Held pre-job safety meeting for tree removal, nipple up, and confined space entry. Bled down and removed remaining flowline sections. Nippled down and removed 2 9/16" 10M x-mas tree and seal flange. Installed 7" 5M x 11" 5M x-over and spacer spools. Installing 11" 5M BOPE @ 2400 hrs.. Walkabout cellar and subbase-Grating in place on cellar top, hands wearing harness and fall protection, safe work permit valid, no exceptions. 9/14/96 Completed nippling up 11" 5M BOP (RSRdA). Changed top and bottom rams to 3 1/2". Pressure tested BOPE. Annular preventer to 250 & 3500 psi.. All valves, gates, and inside BOP to 250 & 5000 psi.. 1st choke manifold valve on manual choke path would not test. Disassembled and inspected valve, seat washed out and no spare on location. Contacted Blair Wondzell with AAOGC, approved continuing operations with valve as is until parts can be attained. Backed out hanger lock downs, tight. Picked hanger off seat, tight pulling off seat, 125K. Circulated one circulation thru choke and gas buster, started circulating with 1100 psi. @ 2.5 bbl/min., loosing fluid (~ 30-45 bbl/hr.. Slowed pump to 600 psi. @ 1.5 bbl/min, and losses slowed to 4-5 bbl/hr., and completed circulating bottom up. Worked packer loose with 30K overpull. Pulled hanger to floor, circulating to stabilize well @ 2400 hrs.. 9/15/96 Completed circulating to stabilize well, considerable amount of gas breaking out dudng first circulation, losses slowed to 2-4 bbl/hr.. Stopped pump and observed well, fluid dropping slowly. POH laying down 3 1/2" injection completion, slow, packer trying to swab. Recovered 10,505' of tubing and jewelry (10,505' + 18.59' original KB = 10,523' top of tubing). Changed top and bottom pipe rams to 2 7/8" and tested to 250 & 5000 psi.. Racking and strapping 2 7/8" ddll pipe @ 2400 hrs.. Both crew held weekly safety meetings. 9/16/96 Completed racking and strapping 2 7/8" drill pipe. Made up BHA #1, dressing mill-5 1/2" csg. scraper-bit sub-xo-bumper sub-jars-xo-(15) 3 1/8" dc's, and RIH picking up 2 7/8' 10.4# S-135 drill pipe. Circulated bottom up (~ 5060' and (~ 7430'. Continuing to RIH picking up drill pipe (~ 2400 hrs.. Page 2 Sheet1 Unocal Corporation Well History Report Well Name: Swanson River-SCU--332-4 Page: 3 9/17/96 Continued to RIH with BHA #1, dressing milt and scraper assembly, picking up 2 7/8" drill pipe to 10,400'. Picked up 3" kelly, kelly cocks and bushings. Pressure tested upper and lower kelly cocks to 250 & 5000 psi.. Washed down from 10,400', taking weight @ 10,510'(dpm). Appears to be tubing top, dress off same. POH and layed down BHA #1, (sim) +6' correction on pick up talley, puts tubing top @ 10,516'(dpm). Functioned BOP's. Make up BHA #2, Baker 5 1/2" SC-2P packer assembly. RIH with BHA #2 @ 2400 hrs.. 9/18/96 00:00-08:30 HRS. RIH WITH SC-2P PACKER ASSY.TAG UP AT 10512'ATTEMPT TO WORK OVER SHOT OVER TUBING STUB "NO-GO" CONTINUED ATTEMPTS WAS ABLE TO IN GAUGE TUBING STUB. 08:30-11:00 HRS.DROP BALL AND PRESSURE UP TO 2500 PSI & SET SCP2P PACKER AT 10448'PRESSURE UP TO 3600 PSI SHEAR OUT BALL.TEST PACKER TO 1500 PSI.RELEASE FROM PACKER. 11:00-12:30 HRS CIRCULATE 2.5 BBL/PER-MIN @ 1000 PSI. 12:30-13:00 HRS.LAY DOWN 5 JOINTS AOH DRILL PiPE 13:00-14:30 HRS.PICK UP KELLY BREAK & LAY DOWN BUSHINGS.REPAIR HYDRAULIC HOSE ON FOSTER TONGS. 14:30-16:00 HRS.CUT AND SLIP 50'DRILLING LINE,CHANGE OIL IN 3412. 16:00-24:00 HRS.POOH LAYING DOWN 2-7/8"DRILL PIPE. 00:00-04:00 HRS.CONTINUE POOH LAYING DOWN DRILL PIPE. 04:00-06:00 HRS.MAKE UP TEST JOINT AND PLUG.CHANGE TOP RAMS TO 2-3/8" 9/19/96 0000-0400 HRS LAY DOWN 2-7/8" DRILL PIPE AND PUT ON TRAILER. 0400-0600 HRS.CHANGE TOP NPIPE RAMS TO 2-3/8".HAD PLUG SET ,TESTED TO 250- 5000 PSI 0600-0800 HRS.RIG LIP HALLIBURTON WIRE LINE & TEST LUBERACATER TO 1000 PSI. 0800-0930 HRS.RUN IN HOLE WITH 1.78"GAUGE SWEDGE.PAST TUBING STUB(g) 10515' TAG UP AT 10669'.POOH. 0930-1030 HRS.RUN IN HOLE WITH PX-PLUG BODY SET IN X-NIPPLE @ 10501'(CHECKED OUT TO BE 10507'SLICK LINE MEASUREMENT 1030-1200 HRS.RUN IN HOLE WITH PRONG,SET IN BODY @ 10501'. 1200-1230 HRS.TEST PX-PLUG AND CASEING TO 2750 PSI.HELD FOR 15 MIN. 1230-1430 HRS.CHANGE OUT 2"PLUGE TYPE VALVE ON ANNULAS,TO 2-1/16"5000.TST VALVE AND CASEING TO 2750 PSI.(GOOD).BOTH 5-1/2"ANNULAS VALVES ARE NOW GATE TYPE WKM. 1430-1530 HRS.RIG UP TO RUN 2-3/8"COMPLETION.DRIFT GLMS & PUPS.HELD PRE JOB SAFETY MEETING, 1530-2400 HRS.RUN 2-3/8"COMPLETION.WITH STANDING VALVE IN PLACE IN X-NIPPLE. 0000-0600 HRS.CONTINUE RUNNING 2-3/8"COMPLETION 0930-1000HRS.PICK UP HANGER & PUP JOINTS FOR SPACE OUT+LANDING JOINT,LAND TUBING AT 1000 HRS. 1000-1030HRS.CLOSE BOP ON LANDING JOINT,PRESSURE UP TO 3000 PSI,TO ASURE HANGER SEALS DO HOLD PRIOR TO SETTING PACKER. 1030-1200HRS.RIG UP HEAD PIN AND TEST LINE TO 4000 PSI.WITH ANNULAS VALVE OPEN PRESSURE UP ON TUBING TO 500 PSI.PRESSURE UP TO 1250 PSI TO SET PACKER.PRESS UP TO 2500,4000 PSI TO FINISH SETTING PROCESS OF PACKER.HELD 4000 PSI FOR 20 MIN FOR TUBING TEST. 1200-1400HRS.RU HALLIBURTON SLICK LINE.RUN IN HOLE RETRIVE STANDING VALVE FROM X-NIPPLE @ 10299'POOH RIG DOWN SLICK LINE. 1400-1500HRS.RIG UP HEAD PIN,PRESSURE UP ON TUBING TO 2750 PSI AND TEST CASEING AND PACKER FOR 30 MIN 1500-1530HHS.RIG UP GLM SET BLANK PLUG. 1530-2200HRS.NIPPLE DOWN BOP. 2200-2400HRS.NIPPLE UP 7-1/16" X 2-9/16"5M SEAL FLANGE AND RISER.UNABLE TO GET P-SEALS PACKED OFF OR TEST. 0000-0330HRS.NIPPLE DOWN SEAL FLANGE.INSPECT P-SEAL PORTS TO ASURE THEY WERE NOT PLUGED.NIPPLE UP SEAL FLANGE.SOAKED PLASTIC IN OIL TO SOFTEN UP PACKING.PACK OFF P-SEALS AND TEST RING GASKET AND HANGER SEALS TO 5000 PSI.TEST P-SEALS TO 5000 PSI. 0330-0600HRS.NIPPLE UP WKM TREE.TEST TO 250-5000 PSI.PULL BLANK PLUG. Page 3 Sheet1 Well Name: SRU-23-22 Unocal Corporation Well History Report Swanson River-SCU--332-4 Page: 4 LOCATION IS GRADED.TUBING PRESSURE 550 PSI.CASEING PRESSURE 340 PSI. 9/21196 0000-0330HRS.NIPPLE DOWN SEAL FLANGE.INSPECT P-SEAL PORTS TO ASURE THEY WERE NOT PLUGED.NIPPLE UP SEAL FLANGE.SOAKED PLASTIC IN OIL TO SOFTEN UP PACKING.PACK OFF P-SEALS AND TEST RING GASKET AND HANGER SEALS TO 5000 PSI.TEST P-SEALS TO 5000 PSI. 0330-0600HRS.NIPPLE UP WKM TREE.TEST TO 250-5000 PSI.PULL BLANK PLUG. 0600-1800HRS.RIG RELEASED FROM DAY RATE,PUT ON STAND BY FOR STEAM CLEANING AND PREP FOR RIG MOVE.ALL TUBULARS,RENTAL EQUIPMENT AND MUD 1800-2400HRS.RELEASED RIG (~ 1800 HRS.WAITING ON DAY LIGHT FOR MOVE TO SRU-23-22.NO CREWS ON LOCATION FROM 2000 HRS ON 0000-0600HRS.WAITING ON DAY LIGHT FOR MOVE THIS A.M. 10/3/96 Schlumberger on location @ 0800 hrs. Production finishing spotting 5 bbls diesel down tubing and pressure up tubing to 2600 psi w/field gas. Hold pre job safety meeting. MU & test lubricator to 5000 psi. Did not have Gamma ray tool on location. Wait 2 hrs on tool. RIH and set down @ 10455 WLM. Log up and make 3 passes at different gain levels trying to attain GR character to correlate. POH and MU ATTB gamma ray w/Cai UB collar Iocator. RIH and set down @ 10476. Log up and correlate, add 26'. Correlation checked by resevoir eng in Anch. POH and MU 35' 1-11/16" EJ3,RDX perf gun w/ 0 deg phasing. RIH and tie in to log wi collar Iocator. 2400-0600 Tie into log perf from 10388 to 10423 per resevoir eng. Good indication of shot on wt indicator. Tubing pressure did not change when fired. Took wt (~ 10370 after shot. Pulled tight (~ 10253 w/end of gun (~ 10294. Attempt to work thru w/75% weak point rating. Coming down freely. After trying to work thur for 1/2 hr line parted at rope socket. POH, had quite a bit of trouble getting last 100' of line up thru pack off. Verify all tools left in hole. Rig dn & move off Schlum. 10/4/96 Tie into log and perf from 10388 to 10423 per resevoir eng. Good indication of shot on wt indicator. Tubing pressure did not change when fired. Took wt @ 10370 after shot. Pulled tight @ 10253 w/end of gun @ 10294. Top of fish @ 10241. Attempt to work thru wi 75% weak point rating. Coming loose on downstroke freely after pulling into tight spot. After trying to work thru for 112 hr line parted at rope socket. POH, had quite a bit of trouble getting last 100' of line up thru pack off. Verify all tools left in hole. Rig dn& move off Schlumberger. Tubing pressure holding (~ 2600 psi. Rig up Pollard .125" slickline @ 1430 hrs. RU 72" lubricator. RIH w/JOC pulling tool, spangs, jars, 11" weight bar w/2 knuckle its. Engage fish ~ 10227 WLM (RKB) on third attempt. Jar on fish for 1 hr w/o movement. Slowly bleed off tubing pressure to 1100 psi while jarring, no movement. Knocked fish loose while attempting to shear running tool. Work fish thru tight spot and POH w/full recovery. Found some wear on blade side of bullnose but not other signs of stuck point. Rig down Pollard. Tubing pressure had built to 1200 psi after 1 hr. Page 4 STATE OF ALASKA · _ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Workover 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Development: 180' RKB feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska, 99519-6247 Stratigraphic: Swanson River Unit Service: X 4. Location of well at surface 8. Well number 1120' FEL, 1040' FNL, Sec. 4, T7N, Rgw, SM SCU 332-4 At top of productive interval 9. P~rmit..number 1911' FEL, 2132' FNL, Sec. 4, T7N, R9W, SM ~30-- CO I ~ ~1~ At effective depth 10. APl number 2025' FEL, 2289' FNL, Sec. 4, T7N, R9W, SM 50- 133-10170 At total depth 11. Field/Pool 2025' FFI, 2289' FNL, Sec. 4, T7N, R9W, SM Swanson ~,~vF-~e~lc~' F r~ 12. Pre~ent we~ condition summary Tota~ depth: measured 11,119 feet P~ugs (measured) trueve ical 10,931 feet AUC 1 199G Effective depth: measured 11,031' feet Junk (measured) Alaska 0il & Gas Cons. commlssi011 true vertical 10,843' feet Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural 30' 22" Yes 30' 30' Surface 1,469' 13-3/8" 1100 sx 1,469' 1,469' Intermediate 4,120' 9-5/8" 350 sx 4,120' 4,118' Production 11,119' 5-1/2" 600 sx 1 st stage 11,119' 10,931' 500 sx 2nd stage Perforation depth: measured 10,470'-10,495'; 10,509'-10,525'; 10,542'-10,630'; 10,665'-10,713'; 10,721'-10,764'; 10,779'-10,825'; 10,833'- 10,875' true vertical 10,294' - 10,319'; 10,333' - 10,349'; 10,366'- 10,454'; 10,749'- 10,537'; 10,545'- 10,588'; 10,603'- 10,649'; 10,657'- 10,699' Tubing (size, grade, and measured depth) 3-1/2", 9.3 #, N-80 to 10,345'; 2-3/8", 4.7#, N-80 to 10,833'. Packers and SSSV (type and measured depth) Baker "FH" pkr @ 10,419'. Brown "H$"-16-1 pkr ~ 10,530'. Brown "HS"-16-1 pkr ¢~ 10,644'. Baker "F" pkr {~ 10,768'. 13. Attachements Description summary of proposal: x Detailed operations program: x BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Gas: Suspended: Name of approver Date approved Service: {gas Iniector 17. I hereby certiht that the foregoing is true and correct to the best of my knowledge. Signed: ~_/~_~e.../// ~l~ Title: Drilling Manager Date: 13-AUG-96 FOR COMMISSION USE ONLY Conditions of apProval: Notify Commission so representative maywitneSSplug integrity BOP Test V Location clearance IAppr°val N°'(~;) - / ~-~{~ Mechanical Integrity Test Subsequent form required 10- J'{ o--~'-'- Original Signed By Tuckerman Babcock Commissioner Date Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE Soldotna Creek Unit Well 332-4 Workover: Recomplete Hemlock Gas Injector to Tyonek Oil Producer Procedure Status: Draf~ #1 Date: July 22, 1996 By: S.S. Lambe/M. Damm ! Facilities Improvement: ~ ~ 1) Tie in header valves. Pressure test to 80% of yield. 2) SI injection gas one week prior to starting workover. Prepare and Kill Well for Workover Rig: 3) Rig up slickline. 4) Pressure test BOP's and lubricator to 5000 psi. MU 1.8" Gauge ring. RIH and gauge tubing to fish at 10, 694'. 5) RU SWS WLU. RIH and Pull GR/CCL from 10,600' to 9,950'. Fax log into office. MU APRS's chemical cutter on SWS's wire and RIH. Cut 2-3/8" tubing ~ 10,520'. 6) Circulate kill weight fluid down tubing taking returns from 3-1/2" x 7" annulus to remove any residual gas. Spot salt based LCM's as required to control fluid loss. Ensure well is dead and holds a column of fluid. Rig Workover: 7) MIRU workover rig. 8) 9) RU lines to pump down tubing and take annular rem. Bleed any gas pressure and circulate down tubing taking returns up casing. Spot salt based LCM's as required. Ensure well is dead. Set a back pressure valve in hanger profile or plug in the tubing for well control. Nipple down tree and nipple up BOP stack. Function and pressure stack to 250 psi an.,cl~l$91~rgl?. Pull back pressure valve or tubing plug as noted in step # 8. 10) MU pulling sub and engage tubing hanger. Back out tubing hanger hold downs. RIH with tubing cutter and cut the 2-3/8' tubing in the middle of full j[ above packer at 10,515'. Release Baker FH packer ~ 10,419'. 11) 12) POOH and lay down 3-1/2" x 2-3/8" injection string and BHA. Install wear bushing. MU casing scraper dressed for 5-1/2" 23# casing. RIH to 10,768' and circulate bottoms up. POOH. Pull wear bushing. 13) MU E-4 setting tool and Baker "SC-2P" retrievable packer assembly (see attached diagram). RIH and set top of isolation packer at 10,460' per corrected tie in log noted in step #14. POOH. 14) Pressure test packer and casing to 2500 psi. Monitor pressure for 15 minutes on a strip chart. 15) Pull wear bushing. 16) PU and RIH with 2-7/8" completion as noted on attached proposed well completion schedule. Set retrievable packer at 10, 265'. Land tubing hanger and secure with hold downs. Pressure test body and neck seals. 17) Set BPV. ND BOP stack. NU tree and pressure test to 5000 psi. Pull BPV. 18) Release rig. NU towlines and pressure test. Unload Well and Flow Back Hemlock: 19) UnlOad well to lifting orifice at 1 bpm. Gas lffi representative be on location to prevent flow cutting of gas lift valves. 20) RU slickline. Pressure test lubricator to 5000 psi. RIH and equalize plug in lower isolation packer. POOH with plug. Record any pressure changes on surface. Open well to production and allow Hemlock zones to clean up and unload water from workover. Isolate Hemlock and Complete Tyonek G-2 Interval: 21) SI well. ReSet isolation plug in profile. Bleed off gas pressure and monitor for pressure build up. Ensure plug is holding. RD slickline. 22) RU E-Line unit. Pressure test to 5000 psi. Establish Safeguards for handling perforating guns. MU 2-1/8" EJ 1II strip guns, 6-SPF, O-Phase guns as noted below. Stack 2000 psi lift gas on tubing. RIH and perforate the following interval. Note initial pressure increase from perforating. Tyonek G-2: 10,385' - 10,420' 2-1/8", EJ III, 6 HPF, O-Phase 23) RD E-line. Allow well to flow to low pressure system unassisted obtaining water cuts and rates for 48 hours. 24) Turn well over to production. Clean up site. UNOCAL RKB to TBG Hanger = 18.59' Tree Connection = 4" 10M Uni-bolt TOC 2835' ~ CMT 5000'- 7516 TOC 8100' DV @ 7516' SIZE 22" 13 3/8" 9 5/8" 9 5/8" 9 5/8" 5 1/2" 5 1/2" 5 1/2" 5 1/2" 5 1/2" 3 1/2" 2-3/8" Swanson rover Field Well # SCU 332-4 Actual Completion 6/1973 CASING AND TUBING DETAIL WT GRADE CONN TOP BOTTOM 0' 30' 54.5# J-55 8rd STC 0' 1469' 43.5# N-80 8rd LTC 0' 186' 47.0g N-80 8rd LTC 186' 3661' 40.0# N-80 8rd LTC 3661' 4122' 23.0g N-80 8rd LTC 0' 1667' 20.0# N-80 8rd LTC 1667' 3897' 17.0# N-80 8rd LTC 3897' 6964' 20.0# N-80 8rd LTC 6964' 9459' 23.0g N-80 8rcl LTC 9459' 11136' Tubing 9.2# N-80 CS Hydril 19.44' 10345' 4.7# N-80 EUE 8rd 10345' 10833' Possible TBG Leak 10,630-35 10694' 5 6 Iol t~9 7 8 9 to e~O 10 11 to, eau's 12 13 14 15 16 to~ 32~ PBTD = 11,015' TD = 11,136' MAX HOLE ANGLE = 17° @ 7,037' NO. Depth 1 18.59' 2 19.24' 3 19.44' 4 10,345' 5 10,376' 6 10,419' 7 10,455' 8 10,486' 9 10,530' 10 10,600' 11 10,643' 12 10,662' 13 10,723' 14 10,766' 15 10,767' 16 10,768' 17 10,833' TOP BTM JEWELRY DETAIL Item Tubing hanger with Cassasco BPV profile XO 3 -3 1/2" CS Hydril pups XO 3 1/2" CS Hydril X 2 3/8" EUE 8rd 2 3/8" CAMCO "MM" GLM .Baker "FH" Packer Otis "S" Nipple Position 2 2 3/8" CAMCO "MM" GLM Brown "HS- 16- l"Packer 2 3/8" CAMCO "MM" GLM Brown 'NS- 16-1" Packer Otis "S" Nipple Position 1 2 3/8" CAMCO "MM" GLM--SCA Plug stuck 5/77 CAMCO "D" Nipple R E C E IV E D Stop sub for seal assy Baker Model "F" Packer w/muleshoeAUG ] ;5 1996 End of tubing tall glaska 0il & Gas Cons. Commission PERFORATION DATA Anchorage ZONE SPF DATE COMMENTS 10,470' 10,495' Hemlock Existing 10,509' 10,525' Hemlock Existing 10,542' 10,630' Hemlock Existing 10,655' 10,713' Hemlock Existing 10,721' 10,764' Hemlock Existing 10,779' 10,825' Hemlock Existing 10,833' 10,875' Hemlock Existing W.S.O @ 10,450' REVISED: 8/7/96 DRAWN BY: TNC UNOCAL( Swanson River Field Well # SCU 332-4 Proposed Completion RKB to TBG Hanger = 18.59' Tree Connection = 2-7/8" Srd TOC 2835'~ CMT 5000'- 7516 TOC 8100' DV @ 7516' 3 4 6 8 9 10 11 12 13 14 15 16 17 18 Possible TBG Leak 10,630-35 Fish 19 20 21 2.2. ~.~-~:';. '.~.~:~:~ ..,:~.~'.x PBTD = 11015' TD = 11136' MAX HOLE ANGLE = 17° @ 7037' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" 0' 30' 13 3/8" 54.5# J-55 8rd STC 0' 1469' 9 5/8" 43.5# N-80 8rd LTC 0' 186' 9 5/8" 47.0g N-80 8rd LTC 186' 3661' 9 5/8" 40.0g N-80 8rd LTC 3661' 4122' 5 1/2" 23.0g N-80 8rd LTC 0' 1667' 5 1/2" 20.0g N-80 8rd LTC 1667' 3897' 5 1/2" 17.0g N-80 8rd LTC 3897' 6964' 5 1/2" 20.0g N-80 8rd LTC 6964' 9459' 5 1/2" 23.0g N-80 8rd LTC 9459' 11136' Tubing: 2-3/8" 4.7# N-80 Buttress 2 3/8" 4.7# N-80 EUE 8rd 10,515' 10,833' JEWELRY DETAIL NO. Depth Item 1 18.59 2 3 4 10,285 5 6 7 8 10,460 9 10 11 12 13 10,515 14 10,530 15 10,600 16 10,643 17 10,662 18 10,723 19 10,766 20 10,767 21 10,768 22 10,833 Tubing hanger w/CIW Type "H" BPV GLM's at 2065',3113',4101',5089',6047', 6765',745 3',8111',8769',9427', 10115', "KBV-22" Anchor Baker "HP- 1 AH" Packer Packer Retrieving Extension "X" Nipple (ID = 1.875") Wireline Re-entry Baker "SC-2P" Packer Packer Retrieving Extension Sliding Sleeve"CMU "X" Nipple (ID = 1.875") Cut-lip overshot Top of Tbg. cut (2 3/8") Brown "HS- 16-1" Packer 2 3/8" CAMCO "MM" GLM Brown "HS-16-1" Packer Otis "S" Nipple Position 1 2 3/8" CAMCO "MM" GLM CAMCO "D" Nipple Stop sub for seal assy Baker Model "F'Packer Tubing tail w/muleshoe PERFORATION DATA Zone SPF Date Comments Top BTM G-2 Hemlock Hemlock Hemlock Hemlock Hemlock Hemlock Hemlock WSO Proposed Existing Existing Existing Existing Existing Existing Existing 10,385' 10,420' 10,470' 10,495' 10,779' 10,825' 10,509' 10,525' 10,542' 10,630' 10,655' 10,713' 10,721' 10,764' 10,833' 10875' *'10,450' O:~DRILLING\SCHEMATIC\GP\GPP\SC3324P.DOC REVISED: 8/7/96 DRAWN BY: MWD 'x · BOP 10". s'OOO pst, PIPE RAMS 10" 8000 BLIND RAMS !0" 5000 KILL LINE 5000 psi 5000 PIPE -RAMS 10" 5000 .... ~ FLOW ~ ±L 'gl -, .e, .,q CHOKE 3" 5000 psi BOP STACK 10" 5000 psi STATE OF ALASKA ALASi/~DIL AND GAS CONSERVATION C("-'~!MISSION REPORi SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing Alter oaaing__ 2. Name of Operator Unoce] 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 m Plugging m Perforate ~ Repair well Pull tubing ~ Other MIT Type of Well: 6. Datum elevation (DF or KB) RKB: 180' 7. Unit or Property name Swanson River Unit Location of well at surface 1120' FEL, 1040' FNL, Sec. 4, T7N, R9W, SM At top of productive interval 1911' FEL, 2132' FNL, Sec. 4, T7N, R9W, SM At effective depth 2025' FEL, 2289' FNL, Sec. 4, '[7N, R9W, SM At total depth 2025' FEL, 2289' FNL, Sec. 4, T7N, R9W, SM 8. Well number SCU 332-4 feet 9. Permit number/approval number 60-19 10. APl number 50-133-10170-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measured true vertical 11,119 10,931 feet Plugs (measured) feet Effective depth: measured 11,031 true vertical 10,843 feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 30' 22' Yes 30' 30' 1469' 13-3/8' 1100 sx 1469' 1469' 4120' 9-5/8' 350 sx 4120' 4118' 11,119' 5-1/2' 600sx 1st stage 11,119' 10,931' =)uu sx zno s~age 10470-10495, 10509-10525, 10542-10630, 10655-10713, 10721 - 10764, 10779-10825, 10833-10875 true vertical 10294-10319, 10333-10349, 10366-10454, 10479-10537, 10545-10588, 10603-10649, 10657-10699 Tubing (size, grade, and measured depth) 3-1/2' to 10345', 2-3/8', 4.7#, N-80 to 10833' 13. Packers and SSSV (type and measured depth) Stimulation or cement squeeze summary Intervals treated (measured) Baker 'FH' pkr. @ 10419', Brown 'HS-16-1' pkr. @ 10530' & 10644', Baker 'F' pkr. @ 10768' RECEIVED 14. Treatment deecription Including volumes used and final pressure APR Representative Dally Avera~3e Production or Inlaclion INItta~ 0ii & Gas Cons, Prior to well operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Anchll~ Pressure Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X_ 16. Status of well classification as: Oil ~ Gas ~ Suspended Service Water Injector Signed ~'}'_~/~7' I berry ce_rtify that thee fo~d Form 10-404 Rev 06/15/88 correct to the best of my knowledge. Date SUBMIT IN DUPI.I~ATE UNOCAL ' WELL SERVICE REPORT WIn,L"0; ..... FmL~) ........ i~Avs: I D&T~: ............ FOREMAN i CONTRACrOR- OPERATION AT TIME OF REPORT: REMARKS: , D C F C.! ~,1 !:: I~ I\ L~,, I.. I ¥ APR 2 2 i99,i htaska Oil & Gas Cons. Commission Anchorage JWE~THE. Jl'EMP. REPORT , , F ~CHILL FACTOR F1 mi. . 'kts. PAGE OF STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COI,9,11SSION Mechanical Integrity Test OPERATOR: qJA.)OC..(:~I FIELD/UNIT/PAD: ,~'l,,J~/~.~ J'~IVE'~' ,~1;I-~1::~ :S C. fJ DATE: ! /.- ~,,~"- ~'.~ , , , PRETEST START ' 15 MIN 30 MIN ....... TBG TIME TIME TIME *P TYPE PACKER REQ CSG TBG TBG TBG WELL *S ANNULUS TVD CASING TBG TEST PRESS CSG CSG CSG START P F NAME *N FLUID MD $1Zl;; IWT I GRADE SIZE PRESS PRESS PRESS PRESS TIME. COMMENTS: COMMENTS: 3/¢- 3 I ,COMMENTS: ~MMENTS: !1 t t I I t t t t t I1' 'TUBING IIUECTION FLUID: p = P~ WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. N = NOT INJECTING c-o~ c- T~p ~ Rle c - h ~t~ ANNULAR FLUID: GRADIENT: WELL TEST: DIESEL Initial GLYCOL . 4- Year ,t" SALT WATER Wod<over DRILLING MUD CRher ~ OTHER OPERATOR REP 8IGNATU~~_ ~ STATE OF ALASKA ,~-,~. _ ALAS~. : AND GAS CONSERVATION CO; 1SSION ~'t APPLICATION FOR SUNDRY APPROVALS // /_ 1. Type ofrequest: Aban~k~__ Suspend __ Alter cuing__ Repair w~H __ Change appr~e<l pro~ram __ , Name of Operator Union Oil Company of California (Unoca0 3. Address P.O. Box 196~47 Anchorage, Alaska 99619-6247 4. Location of well at s~xface Operalione ~hutdown __ Re-enter tuepended well__ Plugging Time exlenelon 8timubte -- P.,t. :_-- 12. Type of Wet ~e X_ 6. Datum elevation (DF or 180' RKB feet 7. Unit or Property name ~wanson River Unit 8. Well number 1120' FEL, 1040' FNL, Sec. 4, T/N, R9W, SM At top of productive Interval 1911' FEL, 2132' FNL, Sec. 4, TZN, R9W, SM At effective depth 2025' FEL, 2289' FNL, Sec. 4, 'ITN, R9W, SM At total depth 2025' FEL, 2289' FNL, Sec. 4, TZN, R9W, SM Present well condition summary Total depth: rneasLred 11119 true vertical 10931 RECEIVED J U L 0 199 Alaska 0il & Gas Cons. C0mmiSS'¢ ~..n.c_h_nrn~a feet Plugs (measured) feet 9. Permit number 10. APl number 50-133-10170-00 11. Field/Pool Swanson River/Hemlock Effeclive depth: meas~xed 11031 feet Junk (measured) true vertical 10843 feet Casing length Size Cemented Measured depth True vertical depth Structural 30' 22' Yes 30' 30' Conductor Surface 1469' 13-3/8" 1100 sx 1469' 1469' Intermediate 4120' 9-5/8' 350 sx 4120' 4118' Production 11119' 5-1/2' 600 ax 1st stage 11119' 10931' r~x) sx 2na $1~ge Uner Perforation depth: measu'ed 10470-10495,10509-10525, 10542-10630, 10655-10713, 10721-10764,10779-10825, 10833-10875 true vertical 10294-10319, 10,333-10349, 10366-10454, 10479-10,537, 10545-10588,10603-10649, 10657-10699 Tubing (size, grade, and measured deplh) 3-1/2' to 10345', 2-3/8", 4.7#, N-80 to 10833' Packers and SSSV (type and meestxed deplh) Baker 'FH' pkr.@ 10419', Brown'H$-16-1' pkr.~ 10530' & 10644', Baker 'F' pkr. @ 10768' 13. Attachments Description summary of proposal __ Detailed operations programX~ BOP sketch _ 14. Estimated date for commencing operation 115. July 20, 1993 16. If proposal was verbally approved Oil m Gas m Name of approver Date approved SeMc, e Injector 17' I here~/icert//~ that.t_~g~j~ <:true.:~.~t,l°°rrect to the best of mY kmwledge' FOR COMMISSION USE ONLY Status of well classification as: Conditiom of approval: Notify Commission so represenlatlve may wltne, Plug Imegrity _ BOP Te~t Location clearance Mechanical Integrity Test~-/~bsequentform required ~'~- Original S~¢.ned By .Approved by the orcler of the Commission David ~L Go,bn. st. on Form 10-403 Rev 06/15/88 IApproval No. Approved Copy Returned Oomrn'i~si°ner Date ~/5'/~ ~ SUBMIT I~ TI~IPMCATE PC & SC Loading and PC Pressure Test SCU 332-4, SR 46 Objective: Well Data: To load the PC and SC and to verify mechanical integrity on the PC per the AOGCC requirements. This testing must be witnessed by the AOGCC before July 1, 1989. PC: SC: Top pkr. depth: Capacities: Current Pressures: procedure: 3-1/2" CS Hydril to 10,345' MD 5-1/2" N-80; 17, 20 & 23# to 11,119' MD 9-5/8" 47# N-80 to 4,120' MD 10,419' MD Tbg x PC = .0103 Bbls/ft. PC x SC = .0438 Bbls/ft. Tbg = 5300 psi; PC = 2350 psi; SC = TR psi 1. Install a two-pen recorder on the well to monitor the SC and PC pressures. 2. Shoot fluid levels on the SC and PC. (Skip to step #10 if no load is needed on the SC or PC). Calculate needed load volumes to fill SC and PC. Assure that this fluid is on location for load. 3. Monitor tbg., PC and SC pressures throughout the Job. 4. Hold safety meeting. 5. RU choke and gas buster to SC, as needed. 6. Blow down SC pressure without allowing fluid production. 7. Hook up pump truck to SC and pressure test lines to 4500 psi. 8. Load SC with lease water containing .25% W1~676 corrosion inhibitor finishing with a 5 Bbl crude cap. Do not exceed 300 psi during pump-in. 9. Repeat steps #5-8 for the PC, as needed, using a 3000 psi maximum injection pressure for step #8. (Several 1,000 psi blowdown/loads may be required). RECEIVED J U L 2 0 1993 Alaska Oil & Gas Cons. Comm~SSiO~ Anchorage PC & SC Loading and PC Pressure Test SCU 332-4, SR 46 Page Two Contact the AOGCC (279-1433) and BLM (267-1243) at least 24 hours prior to testing the PC so that an agency witness can verify the test results. _PC Pressure Test 11. 12. 10. Pressure up PC to 500 psi over current pressure (2,000 psi minimum). Hold for five minutes (observing tbg., PC and SC pressures). If less than 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. Repeat step #11 until 3660 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. 13. RDMO. RECEIVED J U L 2 0 1993 Alaska Oil & Gas Cons. Commission Anchorage t · K.8. 't ' /55' 1~.00~ - GhOUN3 [~/I:L ~ Tu~g H~er 19.~m DOUBL~ ?~t SUB, 3~ Jtm, 3~" ~ ~DR~ 10~12.11m · I it. 2~m ~ 8~ tbs, ~.19~ .. ~ sot' RECEIVED · SCU 332-4 JUL 2 0 1993 CASlN~ 8~ TUBING DETAIL Alaska 0il & 6as Cons. Commissi ,~ SECTION 4 T. ? N.,R. g W. :--~ ..... __ - ~,~' ~ ~' '~__ .... ARCO Alaska, In/~''~'~'~' Post Offic,. tx t00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures July 31, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' 1988-89 UIC Pressure Testing - Swanson River Field Wells SCU 314-4, SCU 332-4, and SCU 321-9 Dear Mr. Chatterton: Attached are Sundry Notices and Well Service Reports which document the production casing pressure tests on gas injection wells SCU 314-4, SCU 332-4, and SCU 321-9. The wells were tested in accordance with Rule 6 of the AOGCC Area Injection Order No. 13. All wells held their required test pressure (within 10%) for 30 minutes. These pressure tests satisfy the requirement to test 25 percent of our Class II wells per year. Please contact Stacy Strickland at 263-4914 if you have any questions concerning this matter. Sincerely, T. S. McCorkle TSM:DML:ch:0003 Attachments cc: G.A. Graham A. R. Kukla UNOCAL Corporation Marathon Oil Company RECE VED AUG 0 71989 Alaska 0il & 6as Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 · STATE OF ALASKA '"'"' r~""SKA OIL AND GAS CONSERVATION COM. ,:SION REPOFIr OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown'__ Stimulate __ Plugging -- Pull tubing Alter casing __ Repair well __ 2. NameofOperator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 5. Type of Well: 4. Location of well at surface 1120' FEL, 1040' FNL, Sec. 4, T7N, Rgw, SM At top of productive interval 1911' FEL, 2132' FNL, Sec. 4, T7N, RgW, Srvl At effective depth 2025' FEL, 2289' FNL, Sec. 4, T7N, Rgw, SM At total depth 2025' FEL, 2289' FNL, Sec. 4, T7N, Rgw, SM Pedorate __ Pull tubing __ Other X H M I T Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 180' RKB 7. U~nit or Prope,,dy name bwanson t~ver Unit' 8. Well number SCU 332-4 9. Permit number/approval number 10. APl number 50-- 133-10170-00 11. Field/Pool Swanson R i ver-Heml ock feet 12. Present well condition summarY Total depth: measured 11,119 feet true vertical 10,931 feet Plugs (measured) Effective depth: measured 11,031 feet Junk (measured) true vertical 10,843 feet Casing Length Size Structural i; 50 ' 22" Surface 1,469' 13-3/8" Intermediate 4, 120 ' 9-5/8" Production 11,119' · 5-1/2" Pedoration depth: Cemented Measured depth yes 30 ' measured 10,470-10,495'; 10,509-10,525'; 1100 sx 1,469' 350 sx 4,1'20' 600 sx 1st stage 11,119' 500 sx 2nd stage 10,542-10,630'; 10,721-10,764'; 10,779-10,825'; 10,833-10,875'. truevertical 10,294-10,319'; 10,333-10,349'; 10,545-10,588'; 10,603-10,649'; 10,657-10,699'. ~bing(siz~gmd~andmeasumdde~h) 3-1/2" to 10,345', 2-3/8", 4.7#, N-80 to 10,833'. PackersandSSSV~ypeandmeasumdde~h) Baker 'FH' pkr @ 10,419'. Brown 'HS'-16-1 pkr ~ 10,644'. Baker 'F' pkr @ 10,768'. 10,366-10,454'; Brown True vertical depth 30' 1,469' 4,118' 10,931' 10,655-10,713'; 10,479-10,537'; 'HS'-16-1 pkr @ 10,530' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl N/A AUG o 71989 .......... u ,.,, & G~s Cons. IJ0rrl111[$8. Casing Pressure Tu~~re Prior to well operation -- Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 33,460 34,024 2,360 5,000 2,250 5,200 16. Status of well classification as: Oil __ Gas __ Suspended __ Service Gas InJector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 Title Cook Inlet Engineering Hanager Date ~'//~ ,~//~ ! SUBMIT IN ~UPLICAIE -- ' ' ~i ii _ ill i l -- ' ..... "" - ............ i _ ,,. , , , .. , , . ,,, , . . . ~_ . . L _ .. , . ............. ii i i IlL II1_ _ i i iii i i '" ............. i1~ J ~ I I ~1111I~1 --~ I _ II I I ..... , . ........... , ..... ~ ' ....... iii i~ ~ Ill I I ............. . ,,,. .... "' -,, i i i Ulll ii i i iii _ i ] I i i I ' I II I~ iiiii i i '~J~II~ ~ FLUID: _'ZO AAC ZS.O30(a) 20 ,MC 25.~I2(c) ~ ,,~,,.,~2~d)--*----- ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-036~ Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures June 14, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached mechanical integrity tests on SCU 314-4, SCU 332-4, and SCU 321-9. This testing is designed to demonstrate tubing and production casing integrity in accordance with the AOGCC Injection Order No. 13, Rule 6. It is being done to satisfy the requirement to test 25% of our Class II wells per year. Plans are to perform the MIT's as soon as possible as the testing deadline for the 1988-89 program is June 30, 1989. Please contact Carol Baker at 263-4643 if you have any questions concerning this matter. Sincerely, T. S. McCorkle TSM: CMB: ch: 0017 Attachment cc: G./~ Graham A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED Alaska Oil & 8as Cons. Commis$lon Anchorage ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany AR3B--6279 , /'-", STATE OF ALASKA '-'" ALA~. ,A OIL AN D GAS CONSERVATION COM M I$.,..ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing m Repair well Change approved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other X 9951l MIT Testing 5. Type of Well: 4. Location of well at surface 1120' FEL, 1040' FNL, Sec. 4, T7N, Rgw, SM At top of productive interval 1911' FEL, 2132' FNL, Sec. 4, T7N, Rgw, SM At effective depth 2025' FEL, 2289' FNL, Sec. 4, T7N, Rgw, SM At total depth 2025' FEL, 2289' FNL, Sec. 4, T7N, Rgw, SM Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 180' RKB 7. Unit or Property name Swanson River Unit 8. Well number SCU 332-4 9. Permit number 10. APl number 50-- 133-10107-00 11. Field/Pool Swanson R i ver-Hem lock feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Surface Intermediate Production ~x Perforation depth: 11,119 feet Plugs (measured) 1 O, 931 feet 11,031 feet Junk(measured) 10,843 feet Length Size Cemented 30 ' 22" yes RECEIVED ;JUN ! 5 989 Alaska 0ii & Gas Cons. C0mmissl0n Measured depth Ari~ical depth 30' 30 ' 10,721-10,764'; 1,469' 13-3/8" 1100 sx 1,469' 4,120' 9-5/8" 350 sx 4,120' 11,119' 5-1/2" 600 sx 1st stage 11,119' 500 sx 2nd stage measured 10,470-10,495'; 10,509-10,525'; 10,542-10,630'; 10,779-10,825'; 10,833-10,875'. 1,469' 4,118' 10,931' 10,655-10,713'; truevertical 10,294-10,319'; 10,333-10,349'; 10,366-10,454'; 10,479-10,537'; 10,545-10,588'; 10,603-10,649'; 10,657-10,699'. Tubing (size, grade, and measured depth) 3-1/2" to 10,345', 2-3/8", 4.7#, N-80 to 10,833'. Packers and SSSV(type and measured depth) Baker ' F ' pkr @ 10,768 '. Baker 'FH' pkr @ 10,419', Brown 'HS'-16-1 pkr @ 10,530', Brown 'HS'-16-1 pkr @ 10,644' 13. Attachments Description summary of proposal __ Detailed operations program _~X BOP sketch X 14. Estimated date for commencing oPeratiOn 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Service Gas __ Suspended Gas I n ject i on 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. signed ~ ~~'~..- .~ 'T'¢ t,,,'t, cCov ~,,.__Title Cook Inlet Engineering Mgr. Date IApproval No. Approved Co~y Returned Commi~ioner FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Zest m Location clearance __ Mechanical Integrity Test ~, Subsequent form required 10- ¢ ORIGINAL SIGNED BY' LONNIE C. SMITH Approved by order of the Commissioner FOrm 10-403 Rev 06/15/88 Date ~¢~//~/~ SUBMIT IN TRIPLICATI~' E-Line BOPE's~ Grease Head/ Hydraulic Packoff RECEIVED ~UN 1 ~ t989 Alaska Oil & Gas Cons. Commission Anchorage Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves Wellhead PC & SC Loading and PC Pressure Test SCU 332-4, SR 46 Objective: Well Data: To load the PC and SC and to verify mechanical integrity on the PC per the AOGCC requirements. This testing must be witnessed by the AOGCC before July 1, 1989. PC: SC: Top pkr. depth: Capacities: Current Pressures: Procedure: 3-1/2" CS Hydril to 10,345' MD 5-1/2" N-80; 17, 20 & 23# to 11,119' MD 9-5/8" 47# N-80 to 4,120' MD 10,419' MD Tbg x PC = .0103 Bbls/ft. PC x SC = .0438 Bbls/ft. Tbg= 5300 psi; PC =2350psi; SC =TRpsi 1. Install a two-pen recorder on the well to monitor the SC and PC pressures. 2. Shoot fluid levels on the SC and PC. (Skip to step #10 if no load is needed on the SC or PC). Calculate needed load volumes to fill SC and PC. Assure that this fluid is on location for load. 3. Monitor tbg., PC and SC pressures throughout the Job. 4. Hold safety meeting. 5. RU choke and gas buster to SC, as needed. 6. Blow down SC pressure without allowing fluid production. 7. Hook up pump truck to SC and pressure test lines to 4500 psi. 8. Load SC with lease water containing .25% wr676 corrosion inhibitor finishing with a 5 Bbl crude cap. Do not exceed 300 psi during pump-in. 9. Repeat steps #5-8 for the PC, as needed, using a 3000 psi maximum injection pressure for step #8. (Several 1,000 psi blowdown/loads may be required). PC & SC Loading and PC Pressure Test $CU 332-4, SR 46 Page Two Contact the AOGCC (279-1433) and BLM (267-1243) at least 24 hours prior to testing the PC so that an agency witness can verify the test results. PC Pressure Test 10. Pressure up PC to 500 psi over current pressure (2,000 psi minimum). Hold for five minutes (observing tbg., PC and SC pressures). 11. 12. If less than 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. Repeat step #11 until 3660 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. 13. RDMO. ---- -- -- - _ _ · , · , i1, _ K.B. /dP' · /~' 19.2,/.' 19...~' 32.95 ' ./.120' D? 0 ?~16' 10,345.0~' - ---- C~O~ID Z~ZL ~o Tubing Ha~ger TubL~g Haan, er ~ PUP Jt~. Top to Bt, re. ?.~8,).72,~2.21 3.59' .65' ' ,201 10312.11' CASING 8~ TUBING DETAIL SECTION 4 T. 7N.,R. 9 w. SWANSON RIVER WELL 312-22 314-2-7 331-27 323-4 332-4 341-4 341-8 312-9 321-9 323 -.9 432-15 , TYPE Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Water Injector STATUS AS OF 1/1/88 Shut-in Shut-in Shut-in Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU13/2c R'EC[21V£D. Alaska Oil & Gas Cons. Commission' Anchorage . Cook ARCO ALASKA, INC. Inlet/New Ventures Engineering TRANSMITTAL TO: ~ FROM: ~ co~,~^~- l/q~m a_~ co.~^,~: //~e ~ DATE' //~ ~ ~ ~ WELL NAME: Transmitted herewith are the following- PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy Receipt Acknowledgment: Return ReCeipt to- ARCO Alaska, Inc. ~.as ~_o~,~. Oo ~. ~ AT.TN: Judy Boegler ATO.-_t~I~a~'J ~m~SS/on Po~ Office Box 100360 Anchorage, AK 99510 ? Wel 1 s under Evaluation for Rate Poten t i a 1 41A-15 '23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 TABLE I Wells being Evaluated for P&A/Future Uti 1 i ty 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A- 33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Producti on i,. 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until Blowdown _ 43A-15 314-27 331-27 '~'343-33'" ATTACHMENT E-I Injection Well Data Water Disposal Wells SRU 31-33W SRU 32-33W SRU 01=33W SRU 21-33W - F Avg. Rate(BPD) 327/4 651 125 2805 Max. Rate(O PD) 8500 #500 /+500 /3500 14500 Avg. PreSs(psi) 769 778 913 735 Shut In Max o Press(psi), 1000 1000 1000 1000 1000 Depth oi 2100 2100 .2..8..82 2..12_0 3100 Depth of Well(ft.) 2061 2520 3000 6660 Gas Injection Wells Ave, Rate(MCFD) Max. Rate(MCFD) SCU 31-#-2 SCU 32-3-4 'SCU 332-~ 3/41-8 U 3t2-9 SGU 321-9 scU 323-9.~ SCU 3#3-33 SRU 332-15 SRU 312-22 SRU 31~-27 SRU 331-2_7 ~ 39,950 35,680 27,640 37,600 30,300 00,000 29,900 35,920 0 0 0 0 0 05000 /+5000 05000 05000 05000 05000 05000 05000 05000 05000 05000 /+5000 05000 o,'/ 5075 5370 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In 5800 '5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 10291 10390 10070 10226 10256 10183 10290 10280 10695 11388 1075~ 11106 10800 11520 10775 11119 10850 1081# 10785 10705 10750 10995 11982 11000 11 #30 11620 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 09-Sep-87 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051950 Field and Pool August 1987 Month and Year of Injection il. WELL NO. 514-4 525-4 552-4 341-4 541-8 512-9 525-9 i545-55 ;412-10 521-9 ~45-4WD 2. API NUMBERIS. C14. FIELDI5. DAYSI TUBING PRESSURE 50- ~ LI & POOL I IN ~ A: CODE I OPER :&. MAXI7. AVERAGE I SI I I PSIG I PSIG I___SI 133-10104-00 IG I 772100 I 50 15,450 155-10106-00 IG I 772100 I 0 I 0 155-10107-00 IG I 772100 I 50 15,500 155-10109-00 ]G I 772100 I 50 :5,550 155-101.20-00 :G I 772100 I 0 : 0 155-10125-00 :G I 772100 : 50 15,550 155-1012&-00 IG I 772100 I 50 15,500 155-10168-00 IG I 772100 I 0 : 0 155-2020~-00 IG I 772100 I 0 I 0 155-10125-00 :G ~ 772100 I 50 15,450 155-10111-00 :D I 772056 ~ 0 *~ *0 I I I I I : I I I I I I I I I I I I I f I I I I I I I I I I I I I I I I I I I I I I 1 : I I I I I I I : : I I I I I I I I I I I : I I I I I I I I I I I I I 4,958 0 5,005 5,141 0 4,945 4,928 0 0 4,991 0 CASING PRESSURE :DAILY AVERAGE INJECTION:TOTAL MONTHLY INJECTION I I 8. MAX 9. AVERAGEIIO. LIQUID II1. GAS I 15. LIQUID I 14. GAS PSIG PSIG I (BBL) I (MCF) I (BBL) I (MCF) ' f I I 5,300 2,559 I I 59,259 I I 1,177,165 0 0 I I 0 I I 0 1,040 656 I I .51,652 I I 948, 2,860 2,576 ~ ~ 57,120 I I 1,115,609 0 0 I I 0 I l 1,240 1,109 I I 40,485 I I 1,214,475 2,600 2,568 I I 55,148 I I 1,054,428 0 0 I I 0 I I 01 0 0 I I 0 I I 1,960 1,815 I I 25,706 I I 771,182 0 0 I 0 I I 0 1 ' I I I I ' I I I I I I I I I I I l 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 l ' ' I I I ' ' I I I ' I I I t ' I I I 1 ' I I I '__ ..... I I I II hereby certify tha~ the foregoing is true and correct to the best of my knowledge I I lSigned ~t~. ~ ~.-~.,~'.~---' I I I ITi~le Da~e I Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE 115. I I I I I I I I I I I I I I I I I : ITOTAL I 0 I 6,279,814 I : Submt~ in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTIONREPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051994 Field and Pool August lq87 Month and Year of Injection :1. WELL NO. I :512-22 :514-27 ~551-27 ~432-15 121-55WD ~51-55WD :52-35WD :41-55WD ! | 2. API NUMBERi5. CI4. FIELD~5. DAYSI TUBING PRESSURE I CASING F'RESSURE :DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION 50- .I LJ & POOL I IN J I ~ t Al CODE J OPER l&. MAXI7. AVERAGEI8. MAXIg. AVERAGEIIO. LIOUID Ill. GAS 15. LIQUID I 14. GAS I S~ ; I PsIG : PSIG I PSIG I PSI8 : (BBL) :___S~ 155-10147-00 ~G ~ 772100. 153-10154-00 18 I 772100 155-10156-00 Iff I 772100 155-10141-00 IG I 772100 155-101&2-00 ID I 77205& 135-20556-00 ID I 772056 i55-10164-00 'ID I 772056 155-10167-00 ID I 772056 I 50 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 t I I I I I I I I I I I I 't 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 . (BBL) I (MCF) I I I 77,581 80,518 &2,11~ 4,352 II hereby certify that the foregoing is true and correct to the best of my knowledge , I I ISigned I 1 I ITitle I Form 10-405 Rev. 12-1-85 Date ~ /~ ~-~ ? INSTRUCT IONS ON REVERSE SIDE 115. ' I I l ' I ' ITOTAL ' I I I I' I I I I I I I I I I 224,.'370 I 0 I I I Submit in Duplicate PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUOHOE BAY PRUOHOE BAY PRUOHOE BAY PRUDHOE 'BAY PRUDHOE BAY PRUDHOE BAY , PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY UNIT S-11 UNIT' S-14 UNIT T-1 UNIT T-7 UNIT U-3 UNIT UNIT U-5 UNIT U-9 UNIT U-lO UNIT X-6 · UNIT X-11 UNIT X-23 UNIT X-24 bNIT X-26 UNIT Y-3 UNIT UNIT Y-6 UNIT Y-7 UNIT Y-11RD PRUDHOE BAY UN I T Y-18 UNIT OR LEASE TOTAL POOL TOTAL · FI ELD TOTAL SWANSON RIVER, HEHLOCK OIL POOL ARCO ALASKA INC SOLDOTNA CK UNIT 314-4 SOLDOTNA CK UNIT 323'4 SOLDOTNA CK UNIT 332-4 SOLDOTNA CK UNIT 341-4 SOLDOTNA CK UNIT 341-8 SOLDOTNA CK UNIT 312-9 SOLDOTNA CK UNIT 321-9 SOLDOTNA CK UNIT 323-9 ......... SOLDOTNA CK UNIT 412,10 SOLDOTNA CK UNIT 343-33 UNIT OR LEASE TOTAL 3o9;534 264,425 174,q67 380,162 602,357 515,072 26h,751 183,322 2~4,173 294,661 149,980 173,544 262,057 282,344 76,492 49,131 84,323 22,223 43,679 306,429 14,519,526 39,536,156 39,536,156 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 84,445,002 88,810,140 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 1,148,650 31 1,080,598 31 871,402 31 1,090,670 31 153,799 6 1,246,967 30 7h9,378 31 1,089,518 31 7,430,982 ;975;o o 7,115,160 1,2ql,472 2,275,7~1 2,727,957 2,791,476 2,551,632 1,790,980 1,767,557 6,174,166 5,618,096 3,530,342 5,273,083 3,169,181 3,942,403 1,968,753 2,653,403 102,640 597,32.1 6,409,296 1,388,876 29h,742,9'15 233,327,280 207,759,340 231,76h,932 218,694,647 304,044,302 33,033,842 170,911,513 111,413,676 - - ENHANCED RECOVERY - - WELL NAHE AND NUHBER ARCO ALASKA INC SWANSON RIV UNIT 331-27 UNIT OR CEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, NICDLE KENAI C OIL POOL UNION OIL C0 CF CALIFORNIA ADL-18731 TRADING BAY ST. A-SRO-2 TRADING BAY ST A-12RD TRADING BAY ST A-26 TRADING BAY ST A-29 UNIT OR LEASE TOTAL POOL TOTAL TRADING BAY, MI~DLE KENAI O OIL POOL UNION OIL CO GF CALIFORNIA ADL-18731 TRADING BAY ST A-SRO-2 TRADING BAY ST A-19 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL ALASKA INDIVIDUAL WELL PRODUCTION FOR MARCH, 1987 OIL(BBL) WTR(BBL) GAS(MCF) DAYS SWANSON RIVER UNIT SHUT-IN 7,430,982 7,430,982 SHUT- ! N ~ ~ ~' ';' ": SHUT- I N SHUT- I N :: . .~.:~ // SHUT- i N / " SHUT-IN SHUT-IN CUH. OIL CUM. WATER ~13,934 15,582,616 ~,~98,822 6,267,061 7,3~8,68~ 21,618,136 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ~ ARCO Alaska, Inc. 110500 SWANSON RIVER FIELD - UNIT 051994 December 1986 ~ Name of Operator Field and Pool Month and Year of Injection I1. WELL:2. API NUMBER~5. C:4. FIELD~5. DAYS: TUBING PRESSURE I CASING PRESSURE :DAILY AVERAGE INJECTION~TOTAL MONTHLY INJECTION NO. 50- 1512-22 514-27 ~31-27 432-15 I LI & POOL I IN I I I I I I Al CODE I OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERAGEIIO. LIQUID Ill. GAS I 15. LIQUID I 14. GAS I 81 I I PSIS I PSIS I PSIS I PSIS I (BBL) I (MCF) I (BBL) I (MCF) I l___SI 155-10147-00 I G I 772100 I - I I 155-10154-00 I G I 772100 I - 155-10156-00 I 0 I 772100 I - 155-10141-00 I B I 772100 I - I ~ I I I I I I ~ l 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 t 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 I · I I I I I I I I~-~ --,.-.~,~ :1.- '.-._3 ' I I I I I I I I I I i~-~l~. I ' I I I I I I I I I I I , : : JAN2n I I I I ...... I I ...... I I I I ~ ~'I 115. I I ~t~s~a Oil & Gas C~;,.i ..... :igiSSlOfi I I I ' I I I ' I I I ' I I I ' ITOTAL I 0 I 0 ' I I Submit in Duplicate II hereby certif)~ that the ~orego~:ng is true and correct to ~he best o{ my knowledge Si ~ned ..................... IT~I~ .... D~ __~/~. ..... I Fo~m 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I I I I I I I I I I I I I I | I I I I ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051950 Fi eld and Pool December 198& Month and Year of Injection ~1. WELL ; NO. I. I I 514-4 : 525-4 -I 552-4 ~ ...... t541-4 ~.. · '='; 541-8 I 512-9 I 525-9 t412-10 ~ 521-9 I I I I ) I I I I 2. API NUMBERIS. CI4. FIELDIS. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION 50- I L~ & POOL I IN I I I I I 81 Al CODE I OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERAGEllO. LIQUID 111. GAS l___SI I 155-10104-00 IG I 772100 I 155-10106-00 IG I 772100 I 155-10107-00 IG I 772100 1 155-10109-00 IG I 772100 I 155-10120-00 IG I 772100 l 155-10125-00 IG I 772100 1 155-10126-00 :G I 772100 ~ 155-10168-00 IG I 772100 I 155-20206-00 IG I 772100 l 155-1012`5-00 IG I 772100 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 PSIG I PSIG I PSIG I PSIG I (BBL) I ...... I I ...... I I 50 15,500 I 5,015 12,500 I 1,560 I 50 1,5,650 I 5,278 15,250 I 1,976 I 50 15,500 I 5,071 I 700 I 594 I 50 I`5,550 I .5~1.57 11~200 I 84~ I ~0 I~O0 I 4~882 11~400 I 1,~48 I ~0 15~000 I 4~6~7 12~850 I 1~267 I 17 I~200 I ~140 11~600 I 1,388 I 0 I 0 I 0 I 0 I 0 I 0 I 0 I 0 I 0 I 0 I 50 15,540 I 5~150 11~600 I 1~08~ I I I I I I I I I t 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 (MCF) 52,501 29,526 24,058 29,951 25,121 55,165 25,550 0 0 20,970 15. LIQUID I 14, GAS I ( BBL ) I I (MCF) 885,785 898,`524 695,626 054,878 I 450,602 I 0 I 0 I 629,091 I I I I I I I I I I I I I I I l ' I I I I I I I II hereby certify that thee +or~gT~ is true and correct to the best o+ my knowledge Si gned ........... p , New Ventures Compliance and Revenue Ti t I e Date ........ Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE 115. I I | I I ITOTAL I '"";""~ ,"" ............ I A .....~,,,' ~.:,:, I I I I' I I I I I I I 0 I 6,288,655 I I Submit in Duplicate LEASE NO. IENHANCED RECOVERYI COHP.DATE ~ ~ STATUS PRODUCT JAN FEB HAR ALASKA INDIVIDUAL WELL ODUCTION FOR 1986 .. YEAR ~ APR HAY JUN JUl. AU~ SEP O~-T NOV DFC TOTAl_ OHM _ ~~ SWANSON RIVER, HENLOCK ARCO ALASKA INC SDLDOTNA CK UNTT 3~-~ APT UNIT051950 OIL 08/15/60 HTR 1GINJ GAS 1055857 1016590 1189909 1165806 1228666 1211657 1257286 1288552 1305706 1125075 1022953 975018 15808633 291785565 SOLDOTNA CK UN'~T A2~-6 AP~ UNIT051950 0IL 0"6/01/61 HTR GINJ GAS 926806 895795 1016689 1021515 1093867 1095936 1110762 1160265 1165222 986857 950909 885785 12305962 250168775 SOt~OTNA CK UNTT 3~2-~ API l~-]n~OT-OO UNIT051950 0IL 06/05/60 WIR lOlNJ OAS 729520 696699 696'207 768356 868986 808659 853755 906629 908923 773879 755068 721133 9663572 20553681~ sntnnTNa CK UNTT . 3~1-& APT ~3-~n]nq-nn UNIT051950 0IL 03/21/60 HTR 1GINJ GAS 96~182 95989? 1105510 100~702 1191630 1125633 1151896 1167267 1162663 98956? 106739? 898526 12718666 218863713 $0t~OTNA CK UNiT 36]-~ APT ~-~nl?n-nn UNIT051950 0IL 07/16/61 HTR 1OINJ GAS 772050 721011 855765 793562 858793 851801 877666 883619 861636 802085 790782 693626 9761772 217Z16264 SOL~OTNA CK UNIT 312-0 AP! UNIT051950 OIL 10/09/60 HTR 1GINJ GAS 1130860 1105266 1275668 1219~56 1266~62 1262821 1268188 1~18592 [$~2222 ~120615 1159677 105q878 SOLDOTNA CK UNiT 321-9 AP! 133-10125-00 UNIT051950 0IL 07/19/61 HTR 1GINJ GAS 787999 '770786 961316 857121 839631 826009 839796 852656 865661 701038 63788~ 629091 9566566 3~111753 SOLDOTNA CK UNIT 323-g APT UNIT051950 0IL 07/17/61 WTR 1GINJ GAS 868162 887705 1037606 I002092 1061656 1027008 1056326 [103668 1110180 1002927 967125 630602 11532633 168163953 SOLDOTNA CK UNIT 412-10 UNIT051950 OIL 06/11/72 HTR ° 1HINJ GAS SOLDOTNA CK UNIT 363-33 UNIT051950 0IL 03/08/61 HTR ' 1GZNJ GAS .., SWANSON RZV UNIT UNIT051996 OIL 10/26/59 HTR ' 1GINJ GAS SHANSON RZV UNIT 34-15 UNIT051996 OIL 08/06/6! HTR 1GINJ GAS API ']33-1016~-OO API 133-10161-00 API 133-10162-00 111~13676 " 6018106 9029539 2056925 6643550 II! !!! 4 ~ LEASE NO. IENHANCED RECOVERYI COMP.DATE + + STATUS PRODUCT JAN FER MAR ~~ SWANSON RIVER, HEMLOCK SWANSON RIV UNIT 512-22 UNITOSigg4 OIL ALASKA INDIVIDUAL WELL~OOUCTION FOR 1986 APR MAY JUN JUL AUg SEP OCT NOV API 133-10147-00 YEAR TOTAL CUM. 873988 08/11/62 HTR 1GINJ GAS SWANSON RIV UNIT UNITOB]qg4 OIL 314-27 API 133-1015~-00 24017269 06/14/60 HTR IGINJ GAS SWANSON RIV UNIT UNITOS]qg~ O~l 331-27 API 133-10156-00 78352178 02/17/58 HTR 1BINJ GAS ARCO ALASKA [NC 282656 OPERATOR TOTALS OIL HATER GAS 7,041,527 7,832,406 8,187,502 8,680,226 7,215,396 8,115,868 8,$69,449 8,393,451 · SWANSON RTVER. HEMLOCK 7,499,819 6,288,655 8,537,995 1,929,187,012 POOL 8,667,789 7,511,775 93,601,665 TOTALS OIL WATER GAS 7,041,527 7,852,406 8,187,502 8,680,226 7,215,396 8,113,868 8,569,449 8,593,451 SWANSON RIVER 7,499,819 6,288,655 8,337,995 1,929,187,012 FIELD. 8,667,789 7,311,775 95,601,665 TOTALS OIL HATER GAS 7,041,527 7,832,406 8,187,502 8,680,226 7,499,819 6,288,655 8,113,868 8,369,449 B,393,451 8,667,789 7,311,775 8,337,995 1,929,187,0~-' 7,215,396 95,601,663 ARCO Alaska, Inc. / Post Office Bu^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 265 6369 John C. Havard Engineering Manager Cook Inlet/New Ventures July 14, 1987 Mr. C. V. Chatterton Alaska Oil& Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Re: Swanson River Unit: Gas Injection Well Production Casing Pressure Tests Dear Mr. Chatterton- Attached are seven (7) Well Service Reports documenting the results of the recent pressure tests conducted on Wells SCU 314-4, SCU 323-4, SCU 332-4, SCU 341-4, SCU 312-9, SCU 321-9, and SCU 323-9. The other active gas injection well, Well SCU 341-8, is currently loaded with kill weight fluid in anticipation of a late-September workover to repair a packer leak. Of the seven gas injection wells tested, only one (Well SCU 323-4) did not meet the criteria stated in Rule 6 of the AOGCC Area Injection Order No. 13. The remaining six wells held their calcu- lated test pressure (within 10%) for 30 minutes. The test pressure for each well was calculated to generate a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the uppermost packer. The surface pressures in Well SCU 323-4 have stabilized at acceptable levels (PC _+1500 psig, SC _+100 psig). We will be retesting this well for integrity in the near future. AOGCC and BLM representatives will be notified 24 hours in advance of this test, should they wish to be onsite. Until that time, we propose to continue injection into this well. If you need additional information, please contact H. F. Blacker at 263-4299. Very truly yours, JCH;JWR:cl-0004 Attachments cc: Mr. Joseph A. Dygas - Bureau of Land Management ARCO Alaska. Inc ~S a Subsidiary of AtlanticRichfieldCompar~y D GHEGK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots &. .Fo.. jic0-s '~November 1983) (Formerly 9--331) ~ED STATES S..,-IT xw 'mi (Other Instructio. a DEPARTMENT OF THE INTERIOR BUREAU oF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drUI or to de, pen or plug back to · different reservoir. Us~ "APPLICATION FOR PERMIT--*' for such prop~MalL) 1. OIL O GAS [] OTHER WELL WELL 2, NAME OF OPERATOR ARCO Alaska, Inc. 3.ADDltESa Or OPERATOR P.O. Box 100360, Anchorage, AK 99510 4. LOCATION Of %YELL (Report location clearly and In accordance with any State requirements,e Se~ also space 17 below.) At surface ; Soldotna Creek Unit - 7 wells o 14. P~RMIT NO. IIlL EleVATIONS (Show whether Dr, wr os, etc.) Form approved. Budget Bureau No. 1004-0135 Expires August 31, 1985 §. LEAII DIIIONATiON AND IIIlll, NO. 6. IF INDIAN, ALL4YI~TBE OB TRIBE NAME ?. UNIT AOBBBMDNT NAME Soldotna Creek Unit g. WELL NO. 10. fIELD AND POOl,; 01 WILDCAT Swanson Rivmr Fiold EUIVBY ORA m uA Sec. 4, 9, T7N, R9W Kenai Alaska 10. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE or INTENTION TO: TEST WATER SHVT-orr ~-~ PULL OR ALTER CASINO FRACTURg TREAT MULTIPLE SHOOT OR ACIDIZB ABANDONO ~EPAIR WEL~ CHANGE PLANS IUBEBQUBNT RBi*OU~2 Of: fRaCTURE TREATMEW? . AL~BEINO CASINO SHOOTING OR ACIDlZlNO ABANDONMENT® (Other) ' (NOTS: Report results of multiple completion on Well (Other) X Pressure Test Completion or Reeompletion Report and Log form.) ~;E.$¢'it[BM I'ROPO8ED OR COMPLETED 0PERATIONM (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting an)* proposed work. If well is direct(oRally drilled, ·ire subourface locations and meastlred and true vertical depths for Rll markers ma~ sones pertl- nen~ to ~is wor~) · The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effec- tive March 16, 1987. To comply with Rule No. 6 - Demonstration of Tubing/Casing Annulus Mechanical Integrity, ARCO Alaska, Inc. is planning on pressure 'testing the production casing annulus of e~ch active gas injection well at Swanson River to a surface pressure sufficient to generate 'a differential pressure of 0.25 psi/ft between the uppermost packer and the formation. The wells included in the program are wells 314-4, 341-4, 312-9, 323-9, 321-9, 323-4, and 332-4. The attached procedures outline the steps that will be taken to conduct the test. The wells are currently being loaded with fluid in the production casing and surface casing annuli. The pressure testing is expected to occur in the last two weeks of June, 1987. RECEIVED JUN- ' Alaska 0il & Gas Co~s. Commission Anchorage 1,~. I hereby certify/that the foreg~gng is tr~e and correct ReEional Engineer TITLE DAT! (This space for Federal or State office use) APPROVED BY COI%?DITIONS OF' APPROVAL, IF ANY: TITLE DATE *See Instructions on' Reverie Side Title l$ U.$.C. Section 100l, makes it a crime for any person knowinKly and willfully to make to any department or agency of the []niteci States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. SCU 323-4 LOAD PRODUCTION AND SURFACE CASIN~;.;~¢~ AND PRESSURE TEST PRODUCTION CASING Loading PC and SC Annulus · Record pressures on the tubing, production casing and surface casing. / Blow down PC .to 1000 psi, recording all pressures. 3. Blow down SC, recording al 1 pressures. . Shoot fluid levels for pump-in volumetrics. Estimated volumes from most recent fluid level data are noted below. Be Load SC with lease water containing l0 gal/lO00 gal WT 676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. . Load PC with lease crude. Do not exceed 2500 psi during pump-in. Do not bleed PC below 1000 psi during pump-in. Pressure Testing) Production Casin9 Note: 24 hours prior to initiating pressure testing procedure, contact the Alaska Oil and Gas Conservation Commission at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. Note: During pressure tests of production casing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communica- tion is noted, cease pressure test and notify Engineering in town. 7. Pressure test PC/SC packoff to 3000 psi. . Pressure production casing to 2000 psi. Hold for five minutes, observ- ing pressures on tubing, production casing and surface casing. If initial pressure is already at or above 2000 psi, proceed to Step4. . If no significant pressure changes occur within five minutes (>50 psi), increase production casing pressure by five hundred psi. Hold pressure for five minutes. 10. Repeat Step 9 until a pressure of 3525 psi is reached. Hold pressure for 30 minutes, noting initial and final pressure on all strings. Volumetrics Fluid Level (3/11/87) Annular Capacity (bbls/ft) Estimated Fluid to surf,a,ce, (bbl,~) Surface Casing 44' .0699 3 Production Casing 5937' .0326 193 ~.. H Ir.. V I*{ l~ 1~1 U. ~.A. qqso - i z DA'TI~ THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - glueline PLEASE CHECK AND ADVISE IMHEDIATELY. c'--oO uo.0,-rdA 0 zE~ 0¢ iT' /: - sz:-q Il · ii 31 ?..-fl~/ _ ii RECEIVED REMARKS ON OTHER SIDE, THIS SHE'E'T C]~W~ON U.S.A. lINC. BOX 7.839 STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION CO,vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 60-019 OTHER [] 3. Address , P. O. BOx 107839, Anchorage, Alaska 4. Location of Well 1120' W & 1040' 99510 S of the N.E. Cor., Sec 4, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 180' K.B. 6. Lease Designation and Serial No. A-028997 8. APl Number 50-133-10107 9. Unit or Lease Name Soldotna Creek.Unit 10. Well Number SCU 332-4 11. Field and Pool Swanson River-Hemlock 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The procedure proposed on the Sundry Notice dated 1/19/81 has been cancelled. NOV ~ ~ ;~:!~ &nohorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si§ned ~ Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: // ~_~ Approved by ,. Form 10-403 Rev. 7-1-80 By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate GH E:V i-%'0 N U. TRANSMITT'A'~ ~ ACKNO~,q,EDGEMENT OF RECEIPT I [';J C. ~\TERIAL- (ALASKA) DEPT.: PLACE: DATE .. THE FOLLOWING IS A LIST OF MATER. IAL ENCLOSED HEREIN. FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. _~' c.,J RECEIVED BY AI,,K~ORAGE. ALASKA 99510 October 12, 1983 ~4r. R. W. ~agee, Area Engineer Chevron U.S.A., Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Re: Subsequent Reports, Sund~ }lotices and Reports on Wells (Form 10-403) Dear Mr. ~gee~ For the following list of "l~otice o~ Intention To:" SunOry Eotic~s and Reports on Wells (form 10-403) this'office does not have on record the "Subsequent ~eport of;" defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. Wel 1 Chevron Date ~_ri~e_~f ._Eg~c_riptign~ 0f !nten..ti.o.n SCU 42-5 12-10-80 Abandon current hemlock completion. -01-19-81 Pull and repair tubing. SRU 312-22 01-19-81 Pull and replace tubing and acidize. SRU 4 lA-15 04-20-81 Pull and rerun tubing and packer. Sincerely, .. . Lonnie C. Smith Commissioner LCS/HJE :lc: 105:D6 TRANSMITTAb/~--~ ACKNO~LEDCEMENT OF RECEIPT g'-"kb\TERIAL - DATE FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline ......... THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. , -~ ~ - ill I .1- · ........ ,3¥~, --33 ... ~, q I~EMARKS ON OTHER SIDE, THIS ALASKA 99510 STATE OF ALASKA ~ ~ -A~ASKA _dL AND GAS CONSERVATION C~...JMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL J~ OTHER [] 2. Name of Operator 7. Permit No. CHEVRON U.S.A. TNC. 3. Address 8. APl Number P. 0. Box 7-839, Anchorage, Alaska 99510 50- 9. Unit or Lease Name Sold0tna Creek Unit 4. Location of Well 1,12'0' West and 1.040' South from the Northeast corner of Section 4. T7N. Rgw, SB&M At producing zone' 1,249' South and 905' West from the surface location 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 180' KB A-028997 12. 10. Well Number SCU 332-4 11. Field and Pool Swanson River Hem.1 _o. c k Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We propose to pull and repair the stub~ngecond in SCU 332-4 per the attached program. We anticipate this work' to begin quarter', 1981. RECEIVED JAN2 2 ]981 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certifv~that the foregoing is true and correct to the best of my knowledge. Signed Title Area Enginee¢ The space below for Commission use / Conditions of Approval, if any: Approved by q Form 10-403 Rev. 7-1.80 COMMISSIONER Date By Order of the Commission Date / ^ ~ ~-~/ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PROPOSAL FOR WELL OPERATIONS PR0-316-1 Field : Swanson River Property and Well No.: Soldotna Creek Unit 332-4 Surface Location: 1,120' West and 1,040' South from the Northeast corner of Section 4, T7N, R9W, SB&M. Bottom Hole Location: 1,249' South and 905' West from surface location. Total Depth: 11,119 feet. Plugs: 11,031 feet.. , Cas.ing_: 22" ConductOr cemented at 30 feet. 13-3/8" 54.5 # J-55 cemented at 1,469 feet. 9-5/8" 40 #. 43.5 # and 47 # N-80 cemented at 4,120 feet. 5½" 17 #, 20 #,-and 23 # N-80 cemented at 11,119 feet. NOTE: 10' flag joint 10,206' - 10,216' E-log depth. 5½" Casing. Detail: Bottom 1,677' 2,495' 3,067' 2,230' (11,119' - 9,442') 23 # N-80 ( 9,442' - 6,947') 20 # N-80 ( 6,947' - 3,880') 17 # N-80 ( 3,880' - 1,650') 20 # N-80 Top 1,650' ( 1,650' - O' ) 23 # N-80 Perforations: See attached Tubing: See attached. Junk: Wireline logging tools in tubing, top at 10,694'. No report of bad casing. Datum: 15' above ground level at original KB elevation of 180'. BOPE Considerations: Gas injection well. Ae B, Ce Maximum anticipated formation pressure is 4600 psi in the Hemlock at 10,450'. A 70 pcf mud will overbalance formation pressure by 400 psi. Maximum possible surface pressure: 3500 psi. Care must be exercised to avoid swabbing the well when pulling injection string. Any kicks should be handled by normal procedures. All personnel should be made aware of these methods. The hole is to be kept full at all times. D. Blowout prevention equipment: Class III - 5000 psi for all work. PROGRAM 1. Pull CEV at 10,376 feet. . Move in contract rig and kill .well with 70 pcf clay base drilling fluid as directed by Production Foreman. 3. Install safety plug in do-nut, remove xmas tree. e · Install and test Class III, 5000 psi.BOPE, including 5000 psi blow and kill lines. Alaska Oil & Gas Conservation Commission and U.S.G.S. to witness test. Remove plug. Be Release packers. Uppermost packer is 2-3/8" x 5½" Baker "FH" at 10,419 feet. Remaining hydraulic p.ackers are 2-3/8" x 5½" Brown HS-16-1 Models at 10,530 feet and 10,643 feet. There are no safety joints. 6. Pull tubing and production equipment. 7. RIH with packer mill and retrieve Ba'ker Model "F" at 10,768 feet. 8. RIH with 4-5/8" bit and clean out to 11,031 feet or as deep as possible. Be Make up hydraulic packers and jewelry on 2-3/8" tubing; run 2-3/8" x 3½" injection string per supplementary program to be furnished. Hydrotest tubing to 6500 psi. 10. Set hydraulic packers. 11. Install plug in do-nut. Remove BOPE and install 10,000 psi injection tree. Test tree to 6500 psi with clean water. 12. Remove plug, release rig. 13. Backflow inter, vals separately to clean up well. Return to injection in selected intervals per supplementary program. RECEIVEo JAN2 2 1981 ~,l~lffi Oil & t~as Cons. Comrniselon Anchorage l '.. H8 '= H9 G L IGS' 18.59' 32.95: II JJP-4 G~OLIND LEVEL ?~o Tubing lle~ger' ' ffubing Hanger 3~z,' CS HYDRIL '"DOUBLE .PIN SUB, 3 PUP Jt~. Top to btm. 7.58,~.72,&2.21 $ . . . . . DETAIL 338 Jto. 3~" CS HYDRIL .65' ..20 ' 13.51 ' {I I ' ' - 1 Jt. 2~" ~gg 8rd ?bg. ' ' "10'455'*04' · ~ "S" NIPPY, Position //2 ............. .- . ~' ~7o' --, 1 Jt. 2~~ E~ 8rd Tbg~ j~ 10,486o64' -- ~ CAMCO 1~2~ I~'~DREL 509' 10312.11' .. ' ' ' i'0,376~23 ' C~<CO ~g< Y~ND~L ' 10,530.25 ' 13.04' 30.19' 5.76' 1.52' . 30.08 ' 13.1'1 ' 54Z~ .= . .655 ....... - : 10,662.0'3 :. 72_ i'- 10~, 723.60 ~6n' 10,7-~.58' 1 Jt, 2~" EUE 8:~t Tbg. BROWN HS -16-1 PACER 2~" x 5~z'' 23/~ PUP J'E. 2~" E~ 8rd Tbg. 2 Jts. 2~" E~ 8rd Tbg. C~2'ICO l'fl~ M~D~L 1 Jt. 2~" Et~ 8~ Tbg. ~ROWN ~-16-~ ~AC]~ 2~" x 5~" 23/t I I PUP Jt. 2~" E~ 8rd Tbgo ~ "S" NIPPY, Position ~ 2 Jts. 2~" E~E 8rd Tbg. CYa~CO F~4 ],~.~D~L ' . . 1 Jt. 2~" EUE 8~ Tbg. ~'"~n "D" IPP~ 10,767.~7' ~ STOP SUB abovo ~AKER "F" PACKER (PK. 10 768) ?.0,768.00 '. --~SEAL for ~L~R "F" PACKER w/X-O to 2~'" . · 2 Jts. 2~" EUE 8rd Tbg · (45 cut ~tm. 10,833.15') -0. Top of Plug 11,03'1 I T.D. 11,119' 30.50 ' 3.92' 3.98' 62.05 ' 13'.07.' 29.90' 3.92' t4o94' 1.47 ' 60.10' 13.00 ' 29°98' .89' 0.53' '?.53' 57.62 ' Zncl'uq,~s X-OW;RS both ends -' ~. ~' . ~,~. I I .@ , IV£L l. H~.4 l~ HO0t~ LIF~ . . C,,.EVRON U.S.A. INC. TRANSMITTAL AND ACKNOWLEDGEbiENT OF RECEIPT OF MATERIAL - (ALASKA) FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. .DATE .PLEASE CHECK AND ADVISE IMMEDIATELY. lBtate of Alaska D[vlslon of O1! & Gas 3001 Porcupine Drive Anchorage. Alaska 99504 e ~""~LASKA) · FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREWITH. CHEC~ AND ADVISE IMHEDIATELY. .-. . . . o . :Received and checked by:,. _ ~: J'- i~':/,_.F'Z~. · · ' · Form .KEV. 9-3~-67 . Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE-. OF ALASKA OIL AND GAS CONSERVATION ,COMMITTEE SUNDRY NoTICEs AND REPORTS ON WELLS. (Do not use this form for proposals to drill or to deepen or plug back to a. diffierent reservoir Use "APPLICATION FOR PERAIrY--" /or such proposals.) OIL ~'] GAS [] Wr-LL WELL OTHER 2. NANiE OF OPERATOR Standard Oil Co. ^LOP. SSS OS OP~'.aATOR P. O. Box 7-839, LOCATION OF WELL Gas Injection Well of Calif. W.O.I. - Operator Anchorage, Alaska 99501 Atsurface 1120' West & 1040' South from N.E. corner of Section 4. At. 'Prod. Zone: 1249' South and 905' West from surface location. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 180 ' Check AppropriateB°x To Indicate Nature of Notice, Re 14. 5. API NLrblEB/CAJ~ CODE 6. LF-JkSE DI~dGNATION A_ND SERIAL NO. A-028997 7, IF LN/)IA/~, ALLOTTEE OR TRIBE 8. UNI~F.~,~dYXOaI~SEN~IS Soldotna Creek Unft 9. W~L NO. SCU 332-4 (32'4) 10. FlED A~ND POOL, OR WILDCAT Swanson River 11. SEC., T., R., M.. (BOTTOM HOL~ OBJECTIVE) 4-T7N, R9W. S.B. & M. 12. PF~P~%ET NO. sort, or Other Data NOTICE OF INTENTION TO: TEIIT WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT .MULTIPLe COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) ~UBSEQUENT RZPORT OF: WATmR sueT-orr ~ I RmPAIRINO WmLL 1 i SHOOTING OR ACIDIZXNG ' ABANDON}I.N, Te CO,he,) Initiat'io'n of Gas Inj. (Nor~: Report results of multiple completion on Well-- Completion or Recompletion Report and Loi form.) 15. DESCRIBEi;ropoaedPROPOSEDwork. OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any Gas Injection initiated December 12, 1967. Initial Gas Injection Rate _+ 10,000 MCF/D. RECEIVED 31 1968 DIVISION OF MINES & MINERAL~ ANC~OP. AGE 16. I hereby certify/that the'~Ore~insLls,true and/corvect'~- - 'C Y~-:.:V?/C'H~'i'~'~i~~: -' -~ TITLE (This space for State o~ce use) District Superintenden~ATm APPROVED BY CONDXTXON~ OF APPROVAL, IF AN~f: TITLE DATE See Instructions On Reverse Side .- }"ul'~ll [) - 7 SUBMIT IN D,_.,x'.~CATE* STATE OF ALASKA <se,, other Ixl- st ructions on OIL AND GAS CONSERVATION COMMITTEE i i i WELl cOMPLETION OR RECOMPLETION REPORT AND LOG* W ELI, %¥ ELL DR V Other b. TYPE OF COMPLE~ON: ;v E L i. OV ER E N BACK nrsva. Other ~ 2. NAME OF OPERATOR '3. A~DgESS OF 0PERkTOR 4. LOCa'rlON OF wELL '-(Report location c~early and in accordance with any State requirements)* At surface At top prod. interval reported below At total depth 13. DANTE SPUDDED 114. DAT~E T.D. RF_~CPIED /15. DA, T~E CO,NiP' SUSP-Oi~ AI~%.ND. /-IOW MANY* ROTARY TOOLS 22. PI~ODUCING INTERVAL(S).OF THIS CO.i~PLETIOA~TOP, BOTTOM, NAME (NrD AND TVD)' 5. AP1 NUM.FA~CAL CODE LEASE DESIGNATION AND SERIAL NO. 7. IF INDiA.N, ALLO'/q'EE OR TRIBE NAM. E 8. UNIT,FAF,.NI OR LEASE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDC&T 11. SEC., T., R., M., (BOTTOM HOLE OI3JECTIVE) 12. PEHa'VIIT N'O. I i 16. ELEVATIONS (DF, RKB, I{T, GR, ETC)*ll7. ELEV. CASINGIIEAD ! INTERVALS DRILLED BY CABI,E TO01,,"] 23. WAS DIRECTIONAL SURVEY MADE 1 24. TYPE ELECTRIC AND OTHER LOGS RUN Illll I Il C~SLNG SIZE ' ' ' ' wi'Il) CASING REC:ORD (Report all strings set in ] f~eq 26. LINER CEMLNTING RECOFJ) TUBING REC OFuD A.?.qOUNT PULLED Il- Ill 1~' I I I · I ~. PEIq~FORAT[ONS OPF._,N TO PRODUC~ON (interval, size and number) /o"/2i' /076¢ /077?_ Io$2~' 30. : PRODUCTION SCI%EEN (MD) SIZE DEPTH SE/' (MD) ~ PACKER SET (NID) Z~/e' /oe76- j 29. ACID, Si:OT, FilAC'IURE, C~',IEXT SQUEXZE, ETC. D~-~TIi INTERVAL (MD) A:MOUNF 2dqD I<!ND OF MA'iE?.IAL USED DATE FIRST PI%ODUCTION J P~P. ODUCT10.N MEIIIO'D (Fiowii~g, gas lift, pumping--size and type of pump, .... [WELL STATUS (Producing or ,. 33. I hereby certify that the foregoing and attached information la complete and correct as determined from all-available records SIGNED TITLE *(See Instruction, and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lan:Is and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc- prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additior~al interval to be seperately produce..':t, show- ing the adlditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). ARY OF FORMATION TE~'I'$ INCLUDIN(; INTERVAL TF_.BTEY), PHF~e-~SUI[E DATA ~ ~COVERI~ OF OIL. GAS, 35. G~GIC MARK~ WAT~ AND MUD I r ,' r , ',, , Form 9-331 (May 1063) ,~ ITED STATES - - S~BMZT IN ~PLIeA~E* "(Other lnstr 'ns on re- DEPAR'[,-,~£NT OF THE INTERIORverseside) -, GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL [~ OAS O OTHER WELL WmLL NAME OF OPERATOR Standard Oil Company of California, W.O.X. - Operator 8. ADDREES OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 4. LOCATION Or WELL (Report location clearly and in accordance with any State requirementLe See also space 17 below.) At surface 1120* West and 1040' South £rom N.E. corner o£ Section 4 At prod. zone 1249' South ~_~d 905* West from surface location. 14. PERMIT NO. 15. ELEVATIONS (Show whether DF,.RT, alt, et~,) - 180' KB Form approved. ~ff~/~'~' Budget Bureau No. 4~*R14~4. LEASE DESIGNATION AND EmRIAL NO, goldStar'., creei~- 8, FARbI OR.LEASE NAME.: ~ '' ,.. :.: ,: ,-,~ q . .- -.. ::' ? ~, .. ,m, . 9. WELL NO.' '. ;. ', SCU 32- - x'..:::' 10. FIELD 'AND PO0b, OR WII?_D(~AT SwanS'~n River · IX. IR0,, T,, I,, M,, OR ILK, SURVEY OB AREA-' '" .4,' s.a. 12. 'COUNTY }~a PA~ISH[ isa: Kenai .Borough'l -:Alaska 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other NOTICE OF INTENT/ON TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT ]--I MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLAN8 SUBSEQUENT RR,POR~ 0Jr: -:- . · -c ,... FRACTURE TREATMENT SHOOTING OR ACIDIZING <Other) Conver~ion ~o (NOTE: Report results 5f multlpl5~ebmpletion on.~Wel! (Other) Completion or Reeomple~ion 17. DESCRIBE PnOPOSEO oa COMPLETED OPERATIONS (Clearly state all pertinent details, and -lye pertinent dates, lncludln~ e~t.'_~nated' date of'Starting an; pro~sed work.. If well is di~etion~y drlH~,, give subsu~e lo~tions and measured and true vertical,.., dept~s.:. L.~ ~1,~ mn~ke~:; ,~d,:,~nes~ m~rtl- nent ~ ~is work.) * Re. Application to co~erc ~o gas injection, dated ~rch 16, 1965. :, .-. ~ ~. = = . -= = -- Co~ers~on Co gas injection c~pleCed April 23, Well returned co produc~i~ April 26, 1965 pendi~ c~enc~ . RECEIVED DIVI,S/O'~ OF MINE,~ & MINERALS ANCHORAGE - C.--V. -GHAq'I~ERTON / District Superintendent (This space for Federal or State ofllee use) APPROVED BY TITLE CONDITIONS OF APPR(~VAL, IF ANY: *See Instructions on Reverm Side · COMPLETION RFPORT - PACKER INSTALLATION STANDARD ,0IL COMPA, NY OF CALIFORN. IA ,-[~ST~N OPERATI.ON.S' ,INC. ,- OPERATOR. AREA: Kenai Peninsula, Cook Inlet Area LALU) OFFICE: Anchorage LEASE NO.: 028997 PROPERTY: SOLDOTNA~ CREEK UNIT WELL NO. SCU 32-4 SECTION 4 Proj. T. 7 N., R. 9 W., Seward B & M LOCATION: Surface: ll20' west and 1040' south at right angles from northwest corner projected Sec. 4:, T. 7 N., R 9 W., Seward B Bottom. Hole: 1249' south and 905' west of surface location. (Dr ojected) ELEVATION: 180' K.B. K. Bo is 15' above ground. DATE' April 2, 1963 C' ~. CHATTERTON, District Superintenden~t CONTRACTOR: Santa Fe Drilling Company, Rig #35 DATE COMMENCED RE~EDIAL WORK: September 22, 1962 DATE COMPLETED R~E~DIAL WORK: September 27, 196Z SU~ARY TOTAL DEPTH: 11,119 ' PLUGS: 11,031' - 11,119' CASING: 22" cemented at 13 3/8"cemented at 9 5/8"cemented at 5 1/2"cemented at PERFORATIONS: As before 30' 1469 ' 4120' 11,119 ' Page 2 COMPLETION REPORT - PACKER INSTALLATION S OLDOTNA CREEK UNIT. 32-4 Section 4 ?rqj. T. 7.N., R..9 W,,..Sewar..d B STANDARD OiL COMPANY OF 'CALIFORNIA %ESTERN OPERATION~' INC. OPERATOR .September 22~, 1.962 Commenced remedial work at 10:O0 AM. Magic Mud. Sep~te.mber 23.~.. 1.9.62 Killed well with 83# pcf Black Magic Mud using Halliburton. tree and installed BOPE. September 24,. 19~,~ Tested BOPE. Attempted to pull tubing loose. September 25, ~96~ Pulled 2 3/8" tubing out of hole. Ran 5 ½" casing scraper. Septembe? 26~,.. 1.962 Pulled scraper. Reran 2 3/8" tubing equipped with packer. Rigged up and conditioned Black Removed x-mas TUBING DETAIL K. B. To ground level G. L. To Landing flange Landing flange and nipple ~2 joints 2 3/8" tubing Otis "S" nipple in position #2 347 joints 2 3/8" tubing Camco Sleeve valve I joint 2 3/8" tubing Brown CC Safety joint Pup joint ~-Brown 2 3/8" X 5½" HS-16-1 packer 2 joints 2 3/8" tubing Camco D Nipple 13 joints 2 3/8" tubing Venturi Shoe Tubing landed at All tubing is 2 3/8", 4.7#, N-80 EUE 8R 15.oo 4.18 1.88 59.17 1.49 10,302.O4 2.43 30.58 ,96 8.03 3.93 57.91 .90 385.62 ~58 ~O,'87~.70 K.B. Depth 19.18 21.06 80.23 81.72 10,383.76 10,386.19 10,416.77 10,417.73 10,425.76 10,429.69 10,487.60 lo, Page 3 COMPLETION REPORT - PACKEH INSTALLATION SOLDOTNA CREEK TJNIT 32-4 Sec ti on 4 Proj. T. 7 N-~ R 9 W., Seward B & M ~"TA-NDARD OIL 'COMPANY OF CALIFoRniA-'~i~N OI~ERATI'ONS,'"INC.' -~opERAT0~ : September 2.7. ~r 1962 Removed BOPE, Reinstalled x-mas tree and tested with 4700~ psi. O.K. Displaced mud with oil and flowed well. Set packer at 10,426'. Rig released at 11:00 PM, September 27, 1962. SRH/sat WELL RECORD INVENTORY Fi e I d: ....... S~_a.p.s.on R_iy_e_r ......................... Locati on ............................ · Ope~a:o~ & Well Name: _ _ . SKanda. rd, ,Oi. 1 Company _ I. Drilling Permit: 2. Survey Plat: 3. Monthly Reports (P-3): 4. Completion Report (P-7): 5. Well History: 6. Other: 7. Miscel t aneous: _ flmldnPna Croak lln~ ~32-4 No. P aoes 2 1 8. Deviation Survey(s)- 9. Wel I Logs: _(_l) z~.~. Total Pages: (2) ~m .(.3) CL&PR _(4) SL-2 i6) ~ (7) (8) ( (]o) m I · I ,11 i i I I I I THE: INTERIOR GEOLOGICAL SURLY .. . ESS : $.: ::MONTHLY REPORT OF OPERATIONS . :~i~'e /ol~o~: ~ a vOrre'c~ report of operations a~d prod~,ctio~ (i'~eh~di~ drilli~ a~d prod~ wells).for Brue M. ~rry titter · ! D 4sion of Mines and Minerals Dept. oi Namra~ Resources e.;:: ..-.': ..: ::: -::'~'l~,:--Th°~ were .~."':(:' ....,%2:,-.~..., ......,.. rur~ or.~.~ off; ......... , ................................. ' ~'~*~:",:: : .... ~-~ .... :;--.:'.~::::- rahs ~ ~ of. ga~Uao dU~ff ~e-mont~' (Write ,'~o" where - . ,; :.. ~,, % ..... :~ ' _ . . . ,-, . : - ~ ,:, .; ': .- . . . PRODUCING DEPARTMENT TELEPHONE 47001 J. T. CROOKER DI~TRI~:T SUPERINTENDENT P. O. BOX 8 3 9 · A N C H O R A G E ° A LA S KA September 9, 1960 CONFIDENTIAL Mr. R. V. Murphy Alaska Oil & Gas Conservation Commission 329 Second Avenue Anchor~ge~ Alaska Dear Sir: Enclosed, herewith~ is the Completion Report on the Soldotna Creek Unit Well No. 32-4 (2) for your information and files. Very truly yours, STANDARD OIL COMPANY OF CALIFORI~zA Western OPerations~ Inc. J. T. CROOKER Enclosure RECEIVED SEP 13 1960 Oil & Gas Section Division of tX/li.,~e~ and /M. inerals l~atura llc~:ou;:ces Alaska l)ept, o[ "' REPORT - NEW WEL~ Lease No. 028~ .......... ~~a~.,~e.-'~, ~.-7 ~...~'9 w.. ~ ~ & a v~q ~ ~ ELEVATION: ~$0' X.B. [ ,, 15' K.~. B. lc/~bc~ve ground. /- "- ......:- _'Vi' _ .... -: ' --'_ PRODUC TI ON: C~ING: SEP 13 1960 Oil & Gas Section l~ t .' Division o[ Mines and Minerals ~' ~ 3~0 ~s ~ ~ · "" " "m,o,883, ~ (s~~) " " " "~i, ~ " " ~ " " " 10,8~- 10,~9', ~', 18~ " " " " " " " ~,76~- 10,7~1', ~3', 173 " " " " " " " ~0,?~3- ~,655', ~', ~33 " " " " " " " 10,~- 10,5~', ~', 353 " " " " " " " 10,5~5- ZO,~9', 16', 65 " 1. Core Ls'bors'torJ~es Hu~ ~)g :l.~t, erv'al 22 - 10~ 119'. 10. Asmew & Sweet Teml~rmture Bm-trey Interval O - ?,hO0'. 3.l, Drlleon Direetio~ml Survey lnter~l 1. NCT $1 on performted l~e~ ~0,833 - ~ln~led in 1:00 AM ~areh ~, 1~0. Drilled 12~" hole -81 pcf~d All 35 ~ts. or~ 1~' ~tal 35 ~ts. or Ce~ente~ at Co~Ar at 1~7', a~d 3 ~aker Centra- lizers at 1~5', ~20', 1~80'. Class III ~. Pressure teste~ to 1500 psi for out Flo~t Collar 1~8' and Shoe 1~69', Firm Cement. O.K. out to 1~00'. 1500' - ~3' 773' arillea 78 per ~ad 1~57' ~rille~ PA~ ~. 81 - 8,3 per m~d a nea 1' ho].. 82 - 83 pef mad 81 - 85 per mad Baa Sehluml)er~r " " ~cro ~og "' I~TI - ~79' ceoa~~~ 9 D/8" easing ~u ~ slr~le areu~ shoe at ~120 ~ 3~ ~ t~ion e~~~ ~~n~~~. U~ 1 ~~~ I ~ ~r pl~. ~~ ~ ~ 1~ ~~s ~ ~~n ~~ ~ ~~d ~ ~g ~s. ~~ ~ ~bl. ~r~~. ~ ~r~t~n ~~. ~~p~s~ ~ - ~si. ~p~s~ ~ psi. A~~ m~~ · ~~t ~- ~ per. ~ 3~. or 1 3t. or · X-Over ~3.~, H-80, 8~, ~ equil~ed vith ~ker flow flllu~ ~ at %1~0'; ~ker Flexiflow Flllup ~ollar at ~', · ~ Baker Cemtr-.1X~er8 at ~100',, ~)~0', in ~02~'. REPORT Removed and reinste~Lled C~s III BOFE. minutes, O. K. DriLled out~ float collar at ~0~' Cleane~ out cement to ~160'. Cleaned out hole with no ee~ent ~160' to 6~81'. Directionall~ Drilled ~" hole ~81' - g~02' 121' drilled _ Dtrectiom~lly d~illed ~" hole 66024 - 7~71' 7~9' drilled Direetionally drilled 8~" hole 7~71' .- 7~' 95' ~et ~mipstock ~ at 7~6' faced S 70° E Directionally ~rille~ 6~" hole 7~' - 7~78' 12' drilled Open~l 6~" hole to 8~" hole~ 7~ ' - 7~78' 12 ' Opened __ Cored 8~" hole 7~78' - 7~' 10' Cored 10' ~o Recevery ~an Schlumberger I-ES log interval Directionally Drilled ~" hole 7~' - 75o~' 16' dr~.'~ lea Pressure tested to 1500 psi for 15 , and shoe at ~120~ pcf ~d. 85 - 92 per mud 75 - 99 per mad COMPLETION REPO~ S~ARD 'OIL CO. '0~ PAS 7- A~r~l ~-3., 26, l~O Directionally ~illed 8~" hole 7~O~' - Set ~ps~ ~ at ~' ~ced S 67° E ~e~d ~" hole ~ ~" ~ ~6' - 10' drille~ 10' Opened ~0' drilled D8 - 99 per mad mreet~onaL~ dr~ed 8~." 8~6' - ~,119' (T.D.) ~gB' ~~ out ~t ~ts as M~s~ ~M ~~~ opemtio~. _ $~l~er~r I-ES log i~e~l 7~ - ~, 1~' Se~er~r ~c ~ intel ~ - ~,1~' S~~er~r ~c~ ~g ~n~~ 6~ - ~,1~' Ce~te~ ~" casi~ in t~ ~s ~ ~ sa~s ~tmction c~t ~ a~d s~. U~d 1 ~t~ ~d 1 t~ ~bber pl~. ~xed ~ ~ bbl. ~ter ~a~. ~d ei~t~n ~~out. A~~ sl~ ~i~t '~ per. p~s. ~~ ~ BBl. ~ter ~a~. ~~ pl~ ~th ~ psi. slu~ ~i~t ~ per. ~d ~si~ ~ 1~,~ ~lon. ............. ~Oi~PLETiON REPORT SO~ CREEK mat 32-~ STAId'OIL CO. '~'F C~J~F01~T/A-O~F/~TOR Top 40 its. or 1667'- Next ~Xt 8O Jts. or ~0~7' Next BOttom ~0 its. or~ Te~al 268 Jts. or ' Above K.B. Lan~ed at - . 2~, N-80, 8R, LT~C 20~, N-80, $~, ~ 17 , Sa, ~, N~, 8R, ~ e~ed ~ ~~ou ~ Co~r at 7~16' ~ ~er Ce~~~r at 7~'. 2~, N~ 8R, ~ ~~ ~ ~er ~~ntial ~11~ Shoe at ~,~', ~er ~e~ati~ Co~r at ~,0~'. ~r C~t~ze~~ on ~t~m ~ Jta., ~ ~r Scmpe~ on 10' ~~ ~t~ at 10,~0 10,910'; 10,7~ - 10,~0'; ~,~ - 10,~70'; 10,~ [ 10,570'; 10,~0 - 10,~'. . R~u~w & Sweet Temperature Survey and located top of emmular cement at Installed and tested BO~E at 1~00 psi for 15 minmtes - O.K. Drilled out cement 7~00 - 7~516'. Drilled out DV collar at 7516' Cleaned out to 10,991'. Drilled out cememt 10,991 - 11,031'. Ran-Schlumberger Neutron -'-Collar Log interval ~ - 11,03~'. . Ran Schlumberger ~et ~un.~ shot 5 ~" holes at Attempted Halliburton WBO .Test on holes at 10,4~0'. No. tezt, tool faile~ to operate properly. Pulled and reran tester. -' ' Halliburton WSO Test on ho~s at !0, ~0'. Tester assembled as follows: 2 outside BT '-Re~or~ers;- '~ -~S~, ~:~' of 2 7/8" ~erfor~ted tailpipe, ~" ~F~e "¢" Book- wall Packer,-VR ~fety Jol~t, l~ulic Jars, spring Tester, ~ Valve ~' above tester on 10,~0~' of 2 7/8" drill pipe. Used 2~45' water Cushion. , · Set Packer at 10, 424'. Opened tool at 7:08 PM for 30 mimmte Init~mal Shut-in pressure. Opened tool to surface at 7:40 for 1 hour flow test; ~" sub*surface bean open 6 minutes - mo blow, 3/8" sub-surface bean open .~. mimmtes - mo blow. Closed tool for 30 minmtes final shut-in. Recovered ~0' net rise, all slightly ~es sy drilling fluid. PRESSURE DA~A ~'" Inside ~T ', 7033 13~ 117~- 117~ 1208 I~ide BT .,. 705~ 57 1091 1091 ~ 67~ ~tside ~ ~ 71~ ~ ~5 ~5 115~ 7019 Test O.K. _ _ , ,1 C~P~-TION REPORT SOLDOTNA CREEK ~SI~ PAOE 9. Ran Schlumberger Jet Gun ~ shot 5 ~°" holes at 10,883' · E~.lli~urton WSO Test. on h~les at 10,883', Tool assembled ~ a~ V~ 1~~ 'ab0~Te~r Jn !0,8~' of 2 7/8" ~11 pi~. Used ~on. Set ~e~r at 10,$~'. ~e~d ~1 at 9:10 ~ for ~ ~~s X~tlal ~u~ p~ssu~. ~ ~1 ~ ~ace at 9:~ for 1 ~ ~ow ~st; ~" sub- _ ~~ ~ cp~ ~ ~~S - fa~ B~w ine~si~ ~ ~ blow in ~ ~~s, 3/8 sub-su~e b~ ~en for ~ ~~s - ~ blow for 2~ ~~s; ~-" blow ~u~ e~i~ pe~od. --No ~s to s~~. Re~ve~d 8~5' 1~0' ~sy ~~ ~~ ~~ ~ ~~ ~r. S~~s at 190 at ~1 tested ~, ~ DATA IH - I~I .~. Inside BT Inside BT Omtside BT Outside BT Ran Casing Scraper, scrap~holes 10, 450' and 10, 883', an~ eondi~lone~ ~. ~an Nalliburton I~ Retaiaer~on 2 7/8" drill pipe and set at 10,767' to s~ueeze holes at 10,883~. Formation broke drown at 5000 psi an~ took fluid at 1 Bbl. mimute rate. Mi~ed !00 seeks construetioa cement to a elurry weight of 116 pcf. l~_~-w~ed in'at 2~00 - ~)00 psi. Fim~l pressure 3000 psi. Preceded cement with 15 bbl. water ~ followed witch 5 Bbls. water. ~8 ~Z~Ates mixtn~ and pumping cement to place. Drilled out cement 10,772 -10,885'. Drilled out retainer 10,767'. Cireula~ to 11,030'. At--ted to run Schl .umber~e.r Jet Gun, stopped 7528'. Pulle~ aad feua~ Jet c~psules broken off. Ran sinker Bar to 11,020'. Attempted 'to rerun SchlumberEer Jet 6~n, etoppe~ 7812'. Pulled am~ fottug Jet capsules broken off. Ran in with ~" Bit on 2 7/8" drill pipe and found Bridge at 8300'. Pushed j~__n~_ tO 11, O20' ~ clretulated. Attempted to rerun Schlumberger Jet Gun, eollar 10cator not operating. Pulled and reran Sehlumberser Jet (~n and shot 5-½" holes at 10,.881'. Tool assembled as above. Used 2680' Set l~e~er at 10,8~'. Op~d tool to surface at 11:20 PM (5-~0-60) for Initial Shut.-in.p~essure. i~eme~ tool to surf&ce at 11:50 PM for 1 bout fi~w test; ~" ~-~r~ ~ open 10 mtmrtes - no blow~ .3<8" .suB.-surfaee bea~ open ~0 mira&tea - ~ ~:~w. 01osed t~ol at 12:50 AM (5 ~1-60) for Final " 'lt~U Sehlua~arge~ Je~ ~ ~ perforate~ ~ ~" ho~s ~r f~t 10,833 - 10,87~' ~', 1~ s~ts. Co~r ~~r f~ ~at 10,83~' ~r ~ . .:./.:. '. ~T_~i om ~les ~,~3 -..~87}_~? ~1 as~~ as abo~ on 10,7~' of 2 7/8" ~ p~6;'- ~e~'~?, ~r ~=oa. ~ ~ at ~:o~ ~ (~ ~) for '~:-:~m~s I~tM ~-~)msm. ~~ ~1 ~ s~aee at ~~ PM for 3 "" ": ;""~at bbw; 3/8" su~~~ ~ ~ 2 ~m ~ ~mtes - ~~st~ blow. Esti~ate~ flow rate with ~ surf&ce Bean - 700 B/D oil an~ 200 M/D ~s. Closed tool at 2~7 AM for:2 hour 8 minutes Fim~l Shut-in pressure. Samples tested as follows: 2:00 AM 2:~0 AM . ~de ~T to 10,923'. CireuJ~ted 2~ hours. l~u Seh~umber~r Jet aun ~ per~orated 1~ ~" holes per foot 10,~ - ;10,825', ~, :IB~ shots. ~ Schlumberger Jet ~An a~ perforated ~ ~" holes per foot followZ~g Lntervals: 10,764- 10,721', ~3', 173 shots 10,713 - 10,65~' ~8' 233 shots 10, 6~0 10, ~2', 88' ~ 3 shots 10,~5 - 10,509',16', ~ shots ~u in with ~" bit aad ¢~ out brid~e ~t 10,~72'. C~d out brid~e fro~ 10~72 - 10,~O'. Cireula~e~ and conditioned Ran ~67 Joints of 2 3/8" ~i~ with Ve~Ari Shoe on bottC~o T~Bing landed at 10, gl'. -~e~mved ~. I~stalle~ X~as Tree. Pressure teste~ Xe~s Tree ~ 3200 psi O. K. Displac~l nm~ with ~O bbl. ~ater follo~w~t with Cru~e OiI d~w~ tubing. Started to flow at ~:00 AM.. Tarn~ to trap at v~ rate for ,3 heur test. Representative flow rates ~ follows: . ~11 Shut-in 7:20 AM, J~me :~, 19~0 pendiag instaJ.l~tion of Pro~uctien Facilities. 300' 1~00': 2202' 2~10' 0o ~5' o~, lO0, 0o 20' 0~ 1~' 1° O' lo0, 0o ~], 0o ~;' REPORT and PLAN of RECEIVED .,,,.,~,,~ O'EC 6 t960 Oil & Gas Section Division ot; Mines and Minerals Alaska Dept. o~ Natural Besourc-~ SUB-SURFACE SURVEY STANDARD OIL OF CALIF. SOLDOTNA CREEK UNIT :32-4 KE.N Al, AL-A $ KA JOB NO.. DA.r~.__APRI L' MA__Y_, 1960 DRILLING CONTROL CORPORATION 3327 LIME AVENUE LONG BEACH 7, CALIFORNIA DRILLING CONTROL CORP. SURVEY DATA SH'BET COMPANY S~'~_ ~fl OIL WELL S01,D0'IRA CEI~U~ ~tt'~IT 32-4 ~:ELD ~ COUNTY__ SHEET NO- JOB NO. STAT£ A~ i "" TRUE RECTANGULAR COORDINATES MEASURED DRIFT VERTICAL DEVIATION,, DRIFT , ~ DEPTH ANGLE DEPTH COURSE DIRECTION NORTH SOUTH EAST WEST , ~ 1° 30~ 3820 O0 31 N 77° E 07 30 OF 2&° 3883 2° 15' 3882 97 55 $ 36° Z 20 I 76 'IBIS ~5 3° 15o ' 3934 ~ 2 95 S 27° E 2 43 3 10 40~0 5° 30* 4029 45 ~ 11 S 26° E 10 '(a~ ? i0 4090 5~ 15' 4069 20 54c) S 27° E 15 52 9 59 4~56 5' 15" 4156 91 6 '22 S 25° E 21 16 I, 12 22 4250 4° O0~ 4248 69 & 42 S 13° E . 27 :.42 13 66 4309 4° 00' 4306 55 4 05 $ O(J° E 31 43 14 23 '~ 4405 '~'~ ....... 4° IS"....... 440:3 28 7 19 S 01° E 38 62 14 35 ' ~;' 4563' t 5° Iff* 4560 62 14 46 S 09° K- 52 ~;0 ~ 16 61 : 4654 6° 30* 4651 04 10 30 S 07° E . 63~13 17~, 87 ~' 4748 · 90 GO0 4743 88 1.~ 70 S O~° K TT TS~ 19 ~' 4842 12.° ~" ,483556 20 75 S 10° I~ ~ '22~. 2,2 .. ,1856 10°. 00. ~ ~ 2! ~ $ 01° . 1~' 65 ':' 2271 4905 10° 00. 48q7 &l 8 51 S 13° # 108 94 20 80 . 4q70 11° 15, ~ 36 12 60 S 25° W 120 44 1'5 44 513~ 10,o. SO* 512'753 30 79 S 25~ ~ .. 148 35 2 43 5290 9° 45~ 5276.35 2S 57 $ 31~ # .. 170 27 10 '74 5444 11°. 00' 5427 52 29 38 S 30° ~ 195 i'1 25 43 5622 11~' 30' 5601 94 35 49 $ 33· W 225 47 44 76 5'/92 12o 15~ 5T68 07 :~ 07 S ~° ~ .. 2~ 02. 65 5917 13° 00~ 5889 87 28 12' S 37° W .. 277 48 82 37 ~r;4 13° 4S* 6042 37 37 ~ $ 39° #' ? 306 48 105 85 DRILLING CONTROL CORP. SUItVEY DATA SHEET DATE J~li~[P I~i~. 1~0 COUN'I;~, SHEET NO. 2 JOB NO. STATE C · ~ TRUE I:U~TANGULAR COORDINATF. S MEASURED D~ DEVIATION DRIFT VERTICAL ,, , REMARKS DEPTH ANGLE COURSE DIRECT/ON DEPTH NORTH SOUTH EAST WEST , , , 6163 13° 15' 6129 00 20 40 $ ~:~o W 323:19 117 55 6318 13° 45' 6279 5~ 36 84 S 35° W ~53 37 1~8 ~8 6461 15° 15 ~ 643~ 81 42 87 $ 35° t~ 388 48 163127 ~0 15° 00' 6551 75 ~0 80 $ 38° # 412 ~5 182 2~ (~02 14° 15' 6747 53 49 73 S 39° W 451 40 213 53 ?037 17° 45~ 6971 34 71 65 S 40~ # 506 29 2~ 59 7123 17~ 15' 7053 47 25 50 $ 44° W 524 ~ 2'/3' ~ 7255 15~ 45' 7180 52 {Fa83 S 450 # 549 q'/' ~ 65 735'{' 15o 00, 7~ 04 26 40 S 43e ,~ 569i -"' 7,1~ 14° -45o 7384 $4 27175 $ 45° ~ 508 340 27 7504 13° I$' . ~. 7421 4~ 8 71 $ 45o # · 595.06 ~46:43 757~ 15o 15' ,7488 59 11581 S 4~° ~ ~ ~ ~57 21 7666 13° 30~ 7596 47 26 37 S 44° ~ ~ 59 375 53 7808 14.0 15' 7716 71 30 04 $ 4~° W . 647 56 396 02 7917 13° 45' 7822 ~8 25 91 5 440 ~q 666 19 414 02 8011 13° '30' 7913 96 21 94 $~48° g 680 ~ 430 ~ 8157 11° 4~" 8056 M 14 4~ S 29° # 705 45 ~ 59 82~5 11° 15' 8191 9 26 92 S N° # 727 76 465 64 ~ 11 ~ 15' '&~18 21 25 17, S -~o W 748 ~8 480 ~ 8~ 12° 15 o 5450 13 28.~5 $ 40° W ~ 33 490 $0 8679. '14° 45' 85~ IT' ~055 $ 41e # ~ ~9 51854 8~63 14° 45~ .S&~ ~ 21 ~ S 42° · 809 29 5~2 85 88~1 14° ~ 8'/42 ~ 24 ~4 S 4~o ~ 82~ 2S 54~ ~ DRILLING CONTROL CORP. SUB, VEY DATA I{HEET SHEET NO. cOMPANY ~~ OIL CSIIP~ Ol~ C/tLI~ DATE COUNTY · lOB NO- STATE. TRUE RECTANGULAI~ COORDINATES MEASURED DRIFT DEVIATION DRIFT VERTICAL DEPTH ANGLE COUP, SE DrRECTION DEPTH NORTH SOUTH EAST WEST , 9103 14o 15' 897(~ (:,9 :~004 $ 47° 1~ 870 0220 14° 15g ~ 09 28 80 $ 44° I~ 890 ?? 611 9415 lg~ 45° 9279 ~ 46. 35 S 48° I~ 921 78 646 11 9510 14° '15' 9371 58 23 38 $ 44° If 930159 662 9568 1¢~ 15' 9427 80 14 28 $ 46° W 948~5I 9~ 14° .30' 9515 O0 22 03 $ 46° W ~ 8! 6M 47 9852 14~, 15, 9702 97 - 41~ ~ S 43o' ~,i 9~9 09 9~32 14° ~' 978~ ~33 20 37 $ 39° ~ 1014 92 7~4 20 10~070 14° ~0' ~)13 93 S4 55 S 37~ ~ 1042 IO,141 14° 15' 99G2 ~5 17 40 $ 36° l~ 105(~65 7fi51 26 · 10,21~~ 14° '30' 10'049 55 .17 2~ 5 ~ ~ 1070 63 ~TT541 10~2{?..0 14° 00' 10~156 28 26 61 $ i]6~ t~ i0')2 15 11~11~) 14~ 00' 10,9 ~3155 193 28 S 36°" 1248 ~.... · . PRoDuCING DEPARTMENT TELEPHONE 47~)01 J. T. CROOKER DISTRICT SUPERINTENDENT P. O. BOX 839 ' ANCHORAGE · ALASKA August h, 1960 .................. RECEIVED' AUG 5 1960 Oil & Cas Section Division o{:,, .~[aska Dept. Mr. R. v. Murphy Alaska Oil and Gas Conservation Commission 329 Second Avenue ~chorage, Alaska Dear ~r. Murphy, Attached please find 'one (1) blue line print and one (1) sepia of the SCU 32-4 (2)composite IES Log, as requested by you. This is forwarded to you under confidential cover. Very truly yours, STANDARD OIL COMPANY OF CALIFORNIA Western Operations, Inc. Attachments UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. ApProval expires 12-31-80. u~...~l~.~ .......... LESSEE'S MONTHLY REPORT OF OPERATIONS stot~ ._l~u~ ................... oou~ty -~'~...p~~ ...... ri~la _..~9.a_.__.~...~.?. .................................... P~ :[ollowi~ is a. oorreet report of operations and prod~etio~ (i~el~di~O dri~lin~ and wells) for the mont~ of _~.~_.,_ ~-~5 .......... ~9~., --'~~z~~ --~ - I I ~bs~per sea zu~ 5, ~x~ ~ 6 ~. b i 1 RECEIVED lee, .B.a.S. - ~~ ~. ~ter (3) ~s~o~-im~~~ I JUL 5 t960 ' ~. ~ ~ ~ Oil & G~s Section Division o[ Mi~es ~nd Minerals Alasks Dept. o[ ~s~ursl ~e~u~ce~ Nor~..--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applleable.) NoT~.--Report on this form is required for each calendar ~nonth, regardless of the statu,s of operations, and must be f~led in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R35§.5. Approval expires .1~-Itl-60. LESSEE'S MONTHLY REPORT OF OPERATIONS The fOllowing is~ a correot report of opera,ions and prod~ction (incl~dir~g drilling and prod~cir~g ~,~o fo~ ~, ~~ .... ~/~_ ...... ~1~' ................. , ~.~., ........ ~~..~~.~ ............................. Jgent's address .... ~_0~_~__~.~ ................................ Company ....... .--~~::~-- ...... ............................... ~--~ ............................ ~e~,a ............... ~._~:-_,..&.,.:~ .... ~ ...................... Phone .................... ~_...~ .......................................... Jffent s t~tle .~~~_~....._~ ....... SEC. AND [ [BARRELS OF OIL (]RAVITY O~ASOLINE WATER (If (I! drilllnzo doi~th: If shut down, oause: J40~ ~{ TwP. RANGE WELL D~Ys CU. F~, or Oxs GALLONS Or BARRZ~ o~ REMARKS NO. P~o~o~ j (~ thou~nds) da~ ~d r~ult of ~t for ~ollne RECOVERED HOB0, S0 state) eon~nt of g~) ~ , . NoT~..--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NoT-.--l~cport on this form is required for each calendar month, regardless of the status of operations, and must bo filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 10--25766-8 U. 8. ¢,U¥£11NM~rNT PnlNTINta orrlc£ // (January 1050) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 12-R356,5. Approval ~xpires .12-31-60. ~ ..iD OFFICE ~~[~ ................ LEASE NUMBER ..~~ .................. LESSEE'S MONTHLY REPORT OF OPERATIONS , , SEC. AND BARRELS OF OIL (]RAVITY (][ASOLINE WATER (I~ (If drilling, depth; if shut down, oatme; ~ Or ~ TWP. RANGE Wr~ D~rs CU. Fr. Or Gts GA~ON8 OF BARRE~ Or REMARKS NO. PRO~O~D (~ thousands) RECOVERED none, so state) date ~d r~ult of t~t for g~ol~e content o~ ..... ~.. , , NoT~,.--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) No?~..--Repor~ on this forxn is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the supervisor by ~he 6th o£ the succeeding month, unless otherwise directed by the supervisor. Form 9-329 ' (January 1950) 16-25766-8 o.s. OOV£RHM£NT PRINTING OFFICE DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LEASE NUMB[R ."ff-~--~-~-~-.L .................... u~T ...... .~Lo.~-.~ ~.. _q~__~ ........ LESSEE'S MONTHLY REPORT OF OPERATIONS The followi~2 ~s a correct report of operations arid prod~otio~ (i~el~din~ drilli~ a~d prod~ei~ff J~e~g' s address __~_L_Q_,___~_~__~_~ .................................. Company .....J~_~,_~~~a,___gIxc., ...... ............................. ~~:~__A~_ ............................. · = .......... . ......................... ~o~ .................. ~SzT:~9~ ............................................... ~en,', SEC. AND I BARRELS OF OIL (~RAVITF (]ASOLINE No. Pao~vo~o (~ tho~) date ~d r~ult o~ t~ for g~ol~e RECOVERED ! i I ce: L, }[. S~~ i . ! ......... NoT~..--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................. runs or sal~s of gasoline during the month. (Write "no" where applicable.) NoT~..--Report on this form is required for each calendar month, regardless of the status of operations, and must bo filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 t (January 1950) ].o---Js?oo-8 u. 8. $OV~'IINM£NI PRINTING orrlcz / UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-1~56.5. Approval expire~ LA.o omcE __.tm~~ ............. LEASE NUMBER _.~~ .................. U~T __~:~~_~~ ........... LESSEE'S MONTHLY REPORT OF OPERATIONS AND TWP. RANOE WELL DAYS I OU. FT. OF GAS GALLONS OF BARRELS Or REMARKS OF ~ NO. ; P~o~omv BARRE~ OF O~ GRAVITY (~ thought) OASOLINE WATER (~ (If drUllng, d~; If shut down, I ~ECOV~RED HOD0~ 80 8~) ~ ~d r~t o~ ~t for g~ol~e oont~t ~ SW-~ Co~ 71~78' - '4~' uo ~co~ ~mctio~.y ~ld ~ ~" hole 7;~ ~ - 7~)~ ~' ,'¢.:, {)ivi':;ion o{' b ;~,t's and Minerals I " ' ~aska Dct't. t t: ~'4atm4 cc: L. {. ..... NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or salas of gasoline during the month. (Write "no" where applicable.) .. NoT~..--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor.., Form 9-3~9 " ($anuary lgS0) 16---25766-~ / i ' 2,020~000 ,x -RECEI.~ Il ~ I L 1 ~PR :~8 Oil & Cas Section 'sion 6[ nines ~and M~nerals" ,&,.~-~,a Dept~ of Natural P~esouxces . . I . _ _ I Illl Well Loe~hbn Zho~)ng 3ur. Loc. 3CU. 41-4. [~ 3~ -4 ~ ~o Y/om Wo le Loc 3C ~ UNITED STATES , DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS The followi~ is a correct report of operatior~s and prod~ctioz~ (i~,cludi~ drillin,~ a~,d prodteoin~ wells) for t~e ~~ _rer&Q~_~o__~___b]~T__, I9__~, _ .... ~$~__~.~._o~.~_ ..................................... ~e~t's address ..... P~___~___~:~__~_~ ............................... St~rd Oil Co. of Caltfo~ Co m pa~ y -~~~.~o~ ~--Znc ............ ......................................................................................... ~ig~ea ................ ~;-T;-~OOKER ................... P~one ..................... ~__~_~_~_ ............................................. ~gent' , title Dt~t~te~-l;::upe~In~~g~8~ SEC. AND DaYs ~U. FT. OF (}AS (]AI,LONS OF BARREL8 OF ~ OF 1~ TWP. RANOE WELL NO. PROD~JC~D BARRELS OF OIL ~RAFITY (In thou~nds) Oxsol,~ Wa~g~ (If RECOVERED llo~e, so stal,P, . NW~ ~ S~~rt~r I-ES 1~71 -~7~, Sor~c 1471 ~c ~log 1471 - 6479 (~chl~b,~r~r Mee.eu~n~ 9 5 ~8" casi~ f~ze ~d ce~n'~d at ~]RO'. Di~ mtio~lly ~illed ~ ho14~ 6~1 6~' At' COOl te ! I '~c~ ~ " , (If drillin~, depth; If shut down, cause; REMARKS dsto sad re~ult o! t~t for pzollne content of Ira~) NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) No~E.--l~epor~ on t-his form is required for each calendar month, regardless o£ ~he s~a~us of opera~ion.q, and must be filed duplicage wi~h the supervisor by ~he 6th o£ the succeeding mon[h, unless o[herwisc directed by ~hc supervisor. Form 9-329 (January 1950) 16---25766-8 u.S. aO'/C~MI~S~' PnlSTISG o~rlc~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R356.5. Approval expir~ 12-31-~0. ~.o oF.cE .... 0~899T ................. LEASE NUMBER ~ ........................ LESSEE'S MONTHLY REPORT OF OPERATIONS Tke followir~ff is a correct report of operations and prodz~otior~ ................. ~~--ox~---c~ ~'~ ~~ ........... ~__o~_,~__~.~ ......................... co~p~.~_~~.:~~~._.:~_~,. .......... ~~ A~ Signed ............. ,)~-~h--~.~,:=~",~ ............................ ............................................................................................. ;~' ,%r, - -, "~'/'"v'- e~o~ ........................... _~__7~ ....................................... ~e~'~ SEC. AND ~ WELL D&~ [ OU. FT. OF OAS GALLONS OF BARRELS Or REMARKS ~ OF 1~ TWP. i RANGE No. P~OD~OSD { BA~E~ OF O~ ORA~ITY (~ tho~) RECOVER~DGASOLINE none,WATERso state)(If (Hds~drilllng,~d r~ultd~th;ofif~t~hUtford°Wn'g~lineOa~e; .... content ~ ~) ~1~ ~2~' ~1,~ ~ ~.~'. C~en~ 13.,~8" cs~ ~ 1~9'. ~ Drl ~ 1~" hol,~ ~ ~ ~'. NoTE,--There were .................. ~ ................. runs or sales of oil; .............................. O ............. M cu. f$. of gas sold; .................................. .0 ........ runs or sales of gasoline during the month. (Write "no" where applicable.) No?n.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--~7a0-s U. ". GOVERNMENT PRINTIH~ OPFICE Form 9-331 a (Feb. 1951) .... ! (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-1~358.4. Approval expires 12-31-60. No .... ~:~?:~j~_~ ............. SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO DRILL ................................. [!~!__ SUBSEQUENT REPORT OF WATER SHUT-OFF ........................ NOTICE Of INTENTION TO CHANGE PLANS .............. . .......... / ...... SUBSEQUENT REPORT OF'SHOOTING OR ACIDIZlNG ................ NOTICE OF INTENTION TO TEST WATER sHut-OFF ............... / ...... SUBSEQUENT REPORT OF ALTERING CASING ....................... NOTICE OF INTENTION TO RE-DRILL OR REPAIR WELL .......... / ....... SUBSEQUENT REPORT OF RE-DRILLING OR REPAIR ................ NOTICE OF INTENTION TO SHOOT OR ACIDIZE .................. / ...... SUBSEQUENT REPORT OF ABANDONMENT .......................... NOTICE OF INTENTION TO PULL OR ALTER CASING .............. / ...... SUPPLEMENTARY WELL HISTORY .................................... NOTICE OF INTENTION TO ABANDON WELL ............ ' ......... / .............................................................................. (INDICATE ABOVE BY CHECK MARK NATURE OF REPORT, NOTICE, OR OTHER DATA) .................................................... ~ .................... 19 ._L,--~--:_:-::J .... , ................................................................................................ (~ ~ec. anA ~ec. No.) (Twp.) (Range) (Meridian) (Field) (County 0r Subdivision) (State 0r ~erri~ry) The elevation of the~/~t~~ above sea level is .:3~:~L ..... ft. ~~", ~ne.~-g~:~, DETAILS Of WORK (Stat~ names of and expected deplhs to objective sands; show sizes, welghts,,and lengths o~ proposed caslngsl tndlcat~ mudding jobs. lng points, and all other importao, t proposed work) I ~nd~rstand thai this plan of work m~st re~elv~ ~ppr~val in writing by the (~eological Eurvey before ~p~r~ion~ __:__::2__.:L '2_ .... :~:: .... ~'L_:L:L_L_";:__:: ...... L:', .... L .... ~:~____' ..... :':__;:_'_: ..... _~___: ................................ Origin zl signed J. T. C;OOt(Et~ By ......... ~.~__~:~..~~ ........................ ....................................................................... T~ lc_ ....... · .... : ............ :: ............... : ...... : .......... GPO 8 62040 , "i APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO DRILL~ DEEPEN [] PLUG BACK [] NAME 01~ COMPANY OR OPERATOR DATE Standard 0il Co. of Oalifornia~ Western Operations, Inc. Address City P. o. Box 7-8~9~ Anchorage, ~ Alaska la/ o State DESCRIPTION OF ~.VELL AND LEASE Name of lease Frmd W. Axford, U.S. Public Dommin I~ven number Elevation (ground) ~ase - ~~...0_~~_ J ~-~ Well location (give footage from section lines) Section--township--range or block & xurvey Field & reservoir (If wildcat, so state) ~ County Soldo~ g~ek U~t ~ Ke~ Distance, in miles, and direction from nearest town or post office · 1.5-~_~lorth Sterling_. Alaska _ Neares~ distance from proposed location to property or lease line: Approx. 1~80 feet Distance from proposed location to nearest drilling, completed or applied--for well on the same lease: feet Proposed depth: _/~_~x. 11,250 Number of acres in lease: Rotary or cable tools Approx. date work will start March 25~ 1960_ .................................. Nu~nber of wells on lease, including this well, cornpleted in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond not required, Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) Well to be direc~ionmlly drilled fi~m. sur~ce ~tion, appmxi~.~ 11~' W ~o~ N section lt~ f~m ~ ~r~r ~n 890' o. o o, at ~t .~es, .~m,~eetion 4~ T. 7 N., R. g W., (See attae2m~en% ',for additior~ lnfozm~tion) CERTIFICATE: I, the undersigned, state that I am the~S'toSUDt, o~ theO~aZ~ 0il CO, Qt~ g~tiforl~& Weste~ Qperation~, Inc. (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated tl~rein are ~true, corr$ct and complete to k.,~ngm~?.~ s~gnec~ the best of my knowledge. J.I. C~OOKE~ / Appr°val D ate: : ~i>~_~_~ff_._~,._ _.. , Approved By: 2" D. D. Bruce, t~'~tr°leum (;e°.log~St Notice: Before ~hdi~k)~ ~fii~{~ha~ ~du~i~u have given ail infor~atiQn ~quested. ~ueh u¢~cessar[ correspond- enee wi~k~dm ~oi~d3.N aturai ncsources See Instruction on Reverse Side of Form Signature Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 ~i:,.~ ~oo of California Creek ~it ~o. 32-i (2) Si8 loc: 10~0~ ~ & 1120~ ~ Sec i, ,~7~,'~9~, S~ S,~L: 2189~ ~ ~ 2025~ ~I,~ Sec 4, ~,~9~, ~ 10713'-1~55~'~ 1~30:*-1~2~, 10525'-I~5~~~ PI~$: II031~ -111,19 ~ Csg~ 22~ ~ 15~ ,5~" ~ 11119o ~f~, ss a s~e & 5~ sx t~ ~llar ~ 7516~ 1-t/t," ~bg, ~u~ ~ I~61~. PRODUGING DEPARTMENT TEL~'PHONE 47~0! J. T. CROOKER DISTRICT ~UPERINTENDENT P. O. BOX 839 · A N C H O R AG E · ALASKA M~rch 23, 1960 25 t9§0 Gil & Cas Section Division o£ Nlines and Minerals ,A.~lla DelF. oi Na~M ~~ ~. Richard Murphy Petroleum Engineer State Division of ~nes & Minerals 329 Second Avenue Anchorage~ Alaska Dear sir: We enclose herewith Alaska O&G Conservation Commission Form~ P-l, Application for Permit to Drill, covering Soldotna Creek Unit 32-4 (2)~ with check in the amount of ~50.00 to cover permit fee. please return the yellow copy indicating the permit number and approval date for our files. ~ours very truly~ STANDARD OIL COMPANY OF CALIFORNIA WESTERN OPERATIONS, INC. J. T.~C OOKER attachments APPLICATION FOR P~,R~%oDP~ ~t~(~R PLUG BACK APPLICATION TO~ N:~ME OF COMPANY OR OPERATOR Standard Ot.l Gol~,ry et Cslifornta, Western ~tations, Inc. Address City State ~R)0I "C" ~ttreet, Anchorage Alaska DESCRIPTION OF \VELL AND LEASE .Npme of lease [ Well number Elevation (~round) Soldotna Creek Unit, Lease ~A-28997 S~ 32-~ 16~' Well location (give footage from section lines) Section~township--range or block & survey I120' West & 10~" $~th from ltor~h-tlmst corner Sec. Field & reservoir (If wildcat, so state) County Swa~ ~ver Field, ge~i Distance, in nqiles, and direction from nearest town or post office Nearest distance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or applied~for well on the same lease: ~h: .~'~t-l~'"'~th ~7.~ ~ ~able tools A.I)prox. date work will start I1' ll ' ---- feet Number of acres in lease: I N umber of wells on lease, including this well, completed in or drilling to this reservoir: ~ (~ludiag ~o If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) CERTIFICATE: I, the undersigned, state that I am t the (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Permit Number: 1965 Approval Date: /', Executive Secretary Notice: Before sending in this form be sure that you have given all information requested. ~uch unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill. Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 Brief Drilling Program as follows: 1. Drill to 1500', log and cement 13-3/8" casing. 2~ Install BOPE consisting of ~000 psi working pressure, double Shaffer ram for complete shutoff an~ ram for shutoff around drill pipe, casing or tubing with a 3000 psi hydrill GE mounte~ directly above the ram for closure on irregular pipe or special plug. Test equipment to 1500 psi working pressure with clear ~water. Directionally drill to 6230'+. Log and cement 9-5/8" casing. Directionally drill to 11,250'± (-10900± SS), log and cement ~" casing in two stages. 5- Determine WSO' s as necessary. 6. Selectively Jet perf attractive sands and test as necessary. 7. Run 2" tubing and complete. I I T 71V ~ F~ g W, 4 SM /0 ---'1 A- oz~,qq7 crc