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161-023
THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Taylor Wellman Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 314-03 Permit to Drill Number: 161-023 Sundry Number: 320-078 Dear Mr. Wellman: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the 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, J sie L. Chmielowski Commissioner DATED this ).6 day of February, 2020. RBDMS (4' FEB 2 5 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.290 RECEIVED FEB 12 2020 ors z(zs( ZB AOGCC 1. Type of Request: Abandon Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to Injection ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC 4 Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 161-023 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10100-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123A Will planned perforations require a spacing exception? Yes ❑ No � ❑ Soldotna Creek Unit (SCU) 314-03 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028997 Swanson River / Hemlock Oil ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,850' 10,848' 10,798' 10,796 -387 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 26 28' Surface 2,002' 11-3/4" 2,002' 2,002' 3,070psi 1,510psi Intermediate Production 10,850' 7" 10,850' 10,848' 6,340psi 31830psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 3-1/2", Tubing Grade: 9.3R / N-80 & L-55, Tubing MD (ft): 10,498', See Attached Schematic See Attached Schematic 2-7/8", & 2-1/16" 6.5p / N-80, & 3.25# / H-40 10,657', & 10,758' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DB Pkr, Baker Fit Pkr, & Brown Collet Stringer 10,500' MD (10,498' TVD), 10,594' MD (10,592' TVD). & 10,658' MD (10,556' TVD) 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: March 1, 2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned [Z r 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Taylor Wellman 777-8449 Contact Name: Ted Kramer Authorized Title: Operation nae Contact Email: tkramer(a�hilcoro.com Contact Phone: 777-8420 Authorized Signature: Dale: '' rs sow COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a -0� 7 �D�� Plug Integrity BOP es[ Mechanical Integrity Test ❑ Location Clearance �L/l'i $ / 2 Other: i1 500 /0.5--c L •'T t C Post Initial Injection MIT Rsq'd? Yes ❑ No ❑ ABDMS FEB 2 5 2020 -L4r-J Spacing Exception Required? Yes ❑ No Mo' Subsequent Form Required: , (� — y (� APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: a -aN ,�u ©,p � GI A 1 p $ al r3(� ta Submit Form and Form 1 403 Revised 4/2017 7l'—Approved applica 'o ii�il r �t�H�► he date of approval. Attachments in Duplicate /r 4 10;20 H Ilikorp AI.Ah . W Well Prognosis Well: SCU 314-03 Date:02/07/2020 Well Name: SCU 314-03 API Number: 50-133-10100-00 Current Status: Shut -In Oil Well Leg: N/A Estimated Start Date: March 1, 2020 Rig: 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 161-023 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Taylor Wellman 1 (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: Current Bottom Hole Pressure: — 5,085 psi @ 10,750' TVD (0.473 psi/ft pressure gradient) Maximum Expected BHP: — 5,085 psi @ 10,750' TVD (Based on normal gradient) Max. Potential Surface Pressure: — 387 psi (Based on the Max. Exp. BHP and a 0.437 psi/ft fluid gradient to Surface) Brief Well Summary: Soldotna Creek Unit 314-03 (SCU 314-03) was drilled and completed as a Hemlock oil well in August, 1961. The well was worked over in April, 1989 which resulted in installing the current three packer completion, for zonal isolation. The well was shut in March, 1998 due to limited flow, and has remained shut-in ever since. JThe purpose of this Sundry is to permanently P&A the SCU 314-03 wellbore. �G As part of this work, Hilcorp requests a variance from 20 AAC 25.112 (b) (1) (A) from setting plugs below and above each perforated interval in the Hemlock formation. The Intervals are currently separated by permanent isolation packers and Hilcorp proposes to set a cement retainer above the upper most packer and squeeze cement all Hemlock perforations. 50' of cement will be left on top of the 7" cement retainer. Also note that the perforated intervals are too close together to isolate with individual CIBP's (w/ 25' of cement on top), even if the three isolation packers could be recovered from the well. Pre - Rig Work: 1. Provide 24 hour notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112(h). Notify BLM of P&A as per 43 CFR 3160 G. L 2. RU Pump Truck. RU on IA and perform a pressure test to 2.000 psi on chart for 30 min. Bleed down pressure. 3. MIRU E -line. Pressure test lubricator to 3,000 psi. j�4.t PU and RIH with 11 Tubing Punch to 10,670'. Punch 4' (10,670'-10,666') in the 2-1/16" tubing tail, Q s�zi�\ above the H-3 perforations. POOH. SCjet 5. ,SPU and RIH with 2nd Tubing Punch to 10,606'. Punch 4' (10,606'— 10,602') in the 2-7/8" tubing above the H-1 perforations. POOH. 6. RU Pump Truck on the tubing and bullhead 9.8�'ppg heavy brine do6n to (& into) the perforations. a. In addition to insuring kill weight fluid at the perforations, this will also ensure fluid injectivity prior to cement squeezing. PU and RIH with Tubing Cutter to —10,497'. Cut 3-1/2" tubing & POOH. RD E -line (rk Well Prognosis Well: SCU 314-03 Hiicarp Alaska, LLQ Date: 02/07/2020 �Ua Rig #401: ` 8. MI RU Rig 401. 9. Set Back Pressure valve. ND wellhead, NU BOP and test 250 low & 2,600 psi high, annular to 250 OD Su psi low & 2,500 psi high. Record accumulator pre -charge pressures and chart tests. Notify AOGCC *� 5 � and BLM 24 hours in advance of test to extend the opportunity to witness. gpP �c5 a. Perform Test. l b. Test VBR rams on 3-1/2" test joint. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Copy to BLM. 0. PU tension on the 3-1/2" tubing string. 11. RU pump truck and circulate the wellbore wit a 9.8 ppg heavy kill weight fluid. (465 X rA 12. POOH with tubing string, laying the GLM and standing back the 3-1/2"" tubing string. 13. PU & RIH with a 7" Cement Retainer, on 3-1/2" tubing. t>r; -Cf ? 14. Set Cement Retainer @ -10,495' (just above 3-1/2" tubing stub). 15. RU cementers and squeeze the Hemlock perforations (by down squeeze method) with 10 bbls of 15.8 ppg cement. a. Note: Tubing+Annular volume= -7.7bbls. 03(L 6d%s � ZS -Z � b. 25% excess pumped/squeezed to ensure perforation isolation 16. Pull out of the Cement Retainer, leaving 75' of cement on top of the retainer (an additional 3 bbls). 17. POOH w/ 3-1/2" tubing, standing back. WOC. 18. Pressure test well to 2,500 psi, for 30 minutes. No f 47 Note: There is no record of a cement bond log (CBL) having been run across the surface casing shoe interval. The only CBL on file (run 7/30/61) logged the interval 4,730'- 10,750'. As there is no record of a CBL having been run across the surface casing shoe, Hilcorp will proceed with the SCU 314-03 abandonment assuming that there is no c nd the 7" casing (across the surface casing shoe interval). CV 4D -ft& "�- erre P�"�� - A f s �L e1619 1. PU & RIH w/ 7" CIBP to 2,152' (+/-) and set same. POOH. ZZ 2.{ PU V set of casing pun_Mand RIH to 2,151'. Punch casing from 2,151' to 2,147'. POOH. & ,Z' 3.51 PU 2nd set of casing punches and RIH to 1,892'. Punch casing from 1,892' to 1,888'. POOH. RD E - line. 4. RIH w/ 3-1/2" tubing to 2,151'. 5. RU Cementers. Spot a 15.8 ppg cement plug from 2,152' up to 1,802' (350' of cement). 6. PU above cement plug and clean out tubing. 7. Pressure up to 500 psi and hold for 30 minutes, to force cement behind the 7" casing (to isolate the surface casing shoe). 8. POOH w/ tubing, laying down. WOC. to/buA 9. Pressure test well to 1,000 psi for 10 minutes./ +-d U 10. RU icklin RIH with Gauge Ring and tag top of cement (TOC). Ensure TOC is at or above 1,902' ? _IZO ensure at least 100' of cement above surface casing shoe). POOH & RD Slickline. 11. RU E -line. PU & RIH w/ 7" CIBP to 160'. Set same. POOH. SW 12. PU Casing Punches and RIH to 159'. Punch casing from 159' to 155'. POOH and RD E -line. P13. Rig up cementers to back side.T-stablish circulation down the IA through the casing punches and p up the 7" casing. Circulate a 15.8 ppg cement plug from 159' to surface. RD Cementers, WOC. 14. Place dry hole tree on well. 15. RDMO Workover Rig. Well Prognosis Well: SCU 314-03 Hil.p Alaska, LLQ Date: 02/07/2020 Post Rig Abandonment Procedures: 16. Excavate cellar, cut off casing 3' below natural GL. 17. Afotifv AOGCC and BLM 48hrs in advance. 18. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10. The following must be bead -welded directly to the marker plate: a Hilcorp Alaska, LLC b. PTD: 161-023 c. Well Name: SCU 314-03 d. API: 50-133-10100-00 19. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 20. Photo document casing cut-off and Welded Plate install. 21. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form 71 3 2,m SCU 314-03 Schematic rorp Alaska. LLC RKB: 149' TD =10,850' PBTD =10,798' MAX HOLE ANGLE = 20 WELL DATA PTD: 161-023 API: 50-133-10100-00 Lease: FED A028997 Spud Date: 06/16/1961 Tree cxn: 3.5" Otis Lift Threads: 3-1/2" SRD Updated by PUN 1/20/2020 PERFORATION DETAIL CASING DETAIL No. Depth Type Size WT I Grade Conn Top Btm. Conductor 22" 2.397" Baker Locator and X -O I.D.2.397 Surf 28' Surface 11-3/4" 47# L-55 8RD Surf 2002' Production 7„ 29# 26# 23# 26# 29# 29# N-80 8RD & BTC N-80 8RD & BTC N-80 8RD & BTC N-80 8RD & BTC N-80 8RD & BTC P-110 8RD & BTC Surf 182' 1118' 4720' 5079' 8564' 182' 1118' 4720' 5079' 8564' 10,850' 2.441" Baker 7" FR Packer 7 TUBING DETAIL 2.313" Otis 2-7/8" "S" Nipple (Position 7 Maybe #3) BTCAB-Mod Tubing Lock -it Tubing AB Mod Tubing 3-1/2" 2.441" N-80 BTC ABM 0 41' 9.3# N-80BTC ABM 41' 10,458' L-55 BTC ABM 10,466' 10,498' Tubing 2-7/8" 6.5# N-80 10,514' 10,657' Tubing 1 2-1/16" 3.25# H-40 10,662' 10,758' WELL DATA PTD: 161-023 API: 50-133-10100-00 Lease: FED A028997 Spud Date: 06/16/1961 Tree cxn: 3.5" Otis Lift Threads: 3-1/2" SRD Updated by PUN 1/20/2020 PERFORATION DETAIL JEWELRY DETAIL No. Depth ID OD Item 1 10,458' 2.992" Merta 3-1/2"x 1-1/2" TPDX GLM T-2 Latch 2 10,498' 2.397" Baker Locator and X -O I.D.2.397 3 10,500' 2.992" Baker 7" Model"DB" Packer w/ 30'Seal Bore 4 10,513' 2.441" X -O SBE x 2-7/8"8RD Pin 5 10,546' 2.313" Otis 2-7/8" "X" Nipple I. D. 2.313 6 10,594' 2.441" Baker 7" FR Packer 7 10,601' 2.313" Otis 2-7/8" "S" Nipple (Position 7 Maybe #3) 8 10,634' 2.441" Camco 2-7/8" MMG GLM w/pup 9 10,657' 2.313" Otis 2-7/8" "D" Nipple (If No -Go nipple it's 2.25") 30 10,658' 1.751" Brown Collet Stringer 11 3-1/2" Gravel Flow Packer Liner WELL DATA PTD: 161-023 API: 50-133-10100-00 Lease: FED A028997 Spud Date: 06/16/1961 Tree cxn: 3.5" Otis Lift Threads: 3-1/2" SRD Updated by PUN 1/20/2020 PERFORATION DETAIL Date Zone Top(MD/TVD) I Btm(MD/TVD) SPF Ft Phase Comments 8/61 Aboie 10,618' 5 1 Cement Squeeze 8/71 10,620' 10,625' 4 5 8/71 H-1 10,629' 10,635' 4 6 8/71 H-2 10,638' 10,645' 4 7 8/61 H-3 10,674' 10,684' 4 10 8/61 10,708' 10,750' 4 42 8/61 H-5 10,756' 5 1 Cement Squeeze WELL DATA PTD: 161-023 API: 50-133-10100-00 Lease: FED A028997 Spud Date: 06/16/1961 Tree cxn: 3.5" Otis Lift Threads: 3-1/2" SRD Updated by PUN 1/20/2020 0- lHilcom Alaska. LLC RKB: 149' Casing Punch: / 355'-159' �h. _j S! A J I a 1,nu7_ .., ✓ 4 9@\\ B d \ Casing Punch: 1,888'-1,892' It x,147'-2,151' 11, 4 2 3 R g � � H-2 ,1 -N- -- -; Tubing Punch: III aL 3]: 10,666'- 10,670' H-3 H-5 'i U. it 7" 10,850' '! TD 10,850' PBTD=0' MAX HOLE ANGLE = 2° SCU 314-03 Proposed Schematic J 5 CASING DETAIL ',4 No. Type G I WT I Grade Conn Top Btm. i 22" 10,498' S c" TubingPunch; 28' Surface 11-3/4" 10,60z'10,606' L-55 8RD Surf 2002' Production 7„ 29# 26# 23# 26# 29# 29# N-80 8RD & BTC N-80 8RD & BTC N-80 8RD & BTC N-80 8RD & BTC N-80 BIRD & BTC P-110 I 8RD & BTC Surf 182' 1118' 4720' 5079' 8564' 182' 1118' 4720' 5079' 8564' 10,850' 10,594' 2.441" II -1 g � � H-2 ,1 -N- -- -; Tubing Punch: III aL 3]: 10,666'- 10,670' H-3 H-5 'i U. it 7" 10,850' '! TD 10,850' PBTD=0' MAX HOLE ANGLE = 2° SCU 314-03 Proposed Schematic WELL DATA PTD: 161-023 API: 50-133-0100-00 Lease: FED A028997 Saud Date: 06/16/1961 Tree an: 3.5" Otis Lift Threads: 3-1/2" 8RD P&A PLUGS & CEMENT Letter: CASING DETAIL JEWELRY DETAIL No. Type Size I WT I Grade Conn Top Btm. Conductor 22" 10,498' 2.397" Surf 28' Surface 11-3/4" 47# L-55 8RD Surf 2002' Production 7„ 29# 26# 23# 26# 29# 29# N-80 8RD & BTC N-80 8RD & BTC N-80 8RD & BTC N-80 8RD & BTC N-80 BIRD & BTC P-110 I 8RD & BTC Surf 182' 1118' 4720' 5079' 8564' 182' 1118' 4720' 5079' 8564' 10,850' 10,594' 2.441" TUBING DETAIL 7 10,601' BTC AB -Mod Tubing Lock -it Tubing AB -Mod Tubing 3-1/2" 9.3# N-80 BTC ABM 0 41' N-80 BTCABM 41' 10,458' L-55 BTC ABM 10,466' 10,498' Tubing 2-7/8" 6.5# N-80 10,514' 10,657' Tubing 2-1/16" 3.25# H-40 10,662' 10,758' WELL DATA PTD: 161-023 API: 50-133-0100-00 Lease: FED A028997 Saud Date: 06/16/1961 Tree an: 3.5" Otis Lift Threads: 3-1/2" 8RD P&A PLUGS & CEMENT Letter: PERFORATION DETAIL JEWELRY DETAIL No. Depth ID OD Item 1 -10,497' 2.992" Top of 3-1/2" tubing stub 2 10,498' 2.397" Baker Locator and X -O I.D. 2.397 3 10,500' 2.992' Baker 7" Model "DB" Packer w/ 10' Seal Bore 4 10,513' 2.441" X-0 SBE x 2-7/8 "8RD Pin 5 10,546' 2.313" Otis 2-7/8" "X" Nipple I.D. 2.313 6 10,594' 2.441" Baker 7" Fit Packer 7 10,601' 2.313" Otis 2-7/8" "S" Nipple (Position? Maybe #3) 8 10,634' 2.441" Camco 2-7/8" MMG GLM w/pup 910,657' 4 2.313" Otis 2-7/8" "D" Nipple (If No -Go nipple it's 2.25") 10 10,658' 1.751" Brown Collet Stringer 11 3-1/2" Gravel Flow Packer Liner WELL DATA PTD: 161-023 API: 50-133-0100-00 Lease: FED A028997 Saud Date: 06/16/1961 Tree an: 3.5" Otis Lift Threads: 3-1/2" 8RD P&A PLUGS & CEMENT Letter: PERFORATION DETAIL Description: A Date Zone Top(MD/TVD) I tm(MD/TVD) SPF Ft Phase Comments 8/61 Above 10,618' 5 1 Cement Squeeze 8/71 H-1 10,620' 10,625' 4 5 Squeezed 8/71 10,629' 10,635' 4 6 Squeezed 8/71 H-2 10,638' 10,645' 4 7 Squeezed 8/61 H-3 10,674' 10,684' 4 30 Squeezed 8/61 H-5 10,708' 10,750' 4 42 Squeezed 8/61 10,756' 5 1 Cement Squeeze WELL DATA PTD: 161-023 API: 50-133-0100-00 Lease: FED A028997 Saud Date: 06/16/1961 Tree an: 3.5" Otis Lift Threads: 3-1/2" 8RD P&A PLUGS & CEMENT Letter: Depth: Description: A 160' 7" CIBP with Cement to Surface B 2,152' 7" CIBP with 250' of Cement on top (TOC at or above 1,902') C 10,495' 7" Cement Retainer w/ 50'of Cement on top (TOC @ `10,455') L 2-1/16" 5M MANUAL GATE VALVE 2-1/16" 5M HCR 7-1/16" 5M ISA SPHERICAL ANNULAR 7-1/16" 5M TRIPPLE RAM IE BOP (BLINDS INSTALLED IN BOTTOM BORE) " 5M DRILLING SPOOL W/ 2-1/16" =TS = STACK BOP, 71/16" -SK YELLOWJACKET L 5 ddN1B O nnnvmen MATERIAL: SEE BOM UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SCU 314-03 (PTD 161-023) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N -HA K Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date \ Qt- \ � Z3 0 Dale A. Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 Operations Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 AUG 2009 Cathy Foerster Commissioner Npskn Oil & 1334 z Cons, CommigAiPin Alaska Oil & Gas Conservation Co mmissiop(ANED OCT 022014r"p'""fA`'''`' 333 W.7 Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, 1 � ctk�_ Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 1442 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 1642 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase 1 Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase 1 Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 H draulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21 A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 23B-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 444 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -81 Colla sed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -81 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -91 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life SARAH PALIN, GOVERNOR r AL& SHA OIL AND GALS 333 W. 7th AVENUE, SUITE 100 CONSIERVA' ION COMMjSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 22, 2009 SCANNED OC -1 0 22014 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(a�alaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 _ Trading Bay Unit D-40RD Union Oil Company of California 178-045 _ Trading Bay Unit G-08RD _ Union Oil Company of California 176-032 _ Trading Bay Unit G-24 _ Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 Trading Bay Unit G-34RD Union Oil Company of California _ 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 Trading Bay Unit K-09 _ Union Oil Company of California 179-016 Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 _ Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 _ Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 _ Swanson Riv Unit 234-15 _ Union Oil Company of California _ Union Oil Company of California Union Oil Company of California 167-076 _ 172-020 173-014 Trading Bay St A-10 Trading Bay St A-23DPN Trading Bay St A-30 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALID Dan Williamson Drilling Manager Commissioner Seamount: July 19, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Commissioner Dan Seamount Re: Sundry Application (Form 10-403) Swanson River Field Soldotna Creek Unit #314-3 Enclosed is a Sundry Application (Form 10-403) for Soldotna Creek Unit Well #314-3. This well is a Hemlock producer which was shut-in during February 1998 after it watered out. Unocal proposes to temporarily shut-off the Hemlock perforations with a plug in the tubing. Then the 7" casing will be pressure tested to 2500 psi. The Tyonek 63-7 sand will be perforated through the tubing and casing at 6155-6167'. Unocal requests a variance for producing this shallow gas interval without a packer. Once the well is completed as a Tyonek gas producer, Unocal will refer to the well as SCU #14-3 instead of #314-3 to remain consistent with well naming criteria at Swanson River. Future plans for the wellbore once the shallow gas interval has depleted may include removing the plug above the Hemlock perforations and running artificial lift equipment to dewater the Hemlock. The expected start date for this well work is July 31, 2000 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263- 7677 or Tim Billingsley at 263-7659. .Sincerely, "M, Dan Williamson Drilling Manager 0 RE C E I V E D' Alaska O;t & Gas Con;S. vUlnmjssion Anchorage AOGCC cover letter 14-3.doc Tim Billingsley 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: X Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x Exploratory: 149 feet 3. Address 7. Unit or Property name P. O. Box 196247 Stratigraphic: Soldotna Creek Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface'" �E�V 8. Well number 650' FS & 690' FWL of Sec. 3, T7N, R9W, SM SCU 314-3 9. Permit number At top of productive interval Same 2 JUL 4 L 10. API2number At effectve depth Sameea a a - .F = y , AjBskB 011 & i -ds t,� ns. Commission 50- 133-10100-00 11. Field/Pool At total depth Anchorage Same Swanson River/Hemlock & Tyonek 12. Present well condition summary Total depth: measured 10850 feet Plugs (measured) true vertical 10850 feet ORIGINAL Effective depth. measured 10798 feet Junk (measured) true vertical 10798 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22" 28' 28' Surface 2002' 11-3/4" 1350 sx 2002' 2002' Intermediate Production 10850' 7" 1900 sx 10850' 10850' Liner Perforation depth: measured See schematic true vertical Tubing (size, grade, and measured depth) 3-1/2" 9.2#, N-80 from surf to 10498'; 2-7/8", 6.5#, L-80 from 10514'-10657' Packers and SSSV (type and measured depth) Baker Model DB 10500', Baker FH @ 10594' 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 7/31/00 Oil: X Gas: Suspended: 16. If proposal well verbally approved: Name of approver Date approved Service: 17. 1 here b rtify t t t f going is true and correct to the best of my knowledge. C12 / Signe illiamson Title: Drilling Manager Date: 'C.Q2 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Test r/ Location clearance 00 " Mechanical Integrity Test Subsequent form required 10- d '� Approved Copy Returned ORIGINAL SIGNED BY db D Taylor Seamount IkW Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE -0w SCU 314-3 (After Recompletion will be Named SCU 14-3) 7/17/00 Pro osed Plu back of SCU 314-3 1) RU slickline. Run PX plug and set in 2.313" X nipple pp at 10,546'. 2) Pull dummy valve from gas lift mandrel at 10,458'. RD sllckline. 3) Load tubing and 3-1/2" x 7" annulus with 9% KCl. 4) Pressure test tubing and casing to 2500 psi. NotifyBL possible witness of pressure test. Mand AOGCC for Expected reservoir pressure of proposed 63-7 sand at 6155' 2770 psi Highest anticipated tubing pressure at surface = 2770 psi — (0.06 gas gradient x 6155') - 2400 psi 5) RU E -line. Perforate tubing and 7" casing at: 6155'-6167' Tyonek 63-7 Sand 6) Flow gas and water to clean up well. Run 4oint test. t. 7) Return well to production. RECEEVEI3 JUL 2 4 2000 Alaska U4 Gas Com, ('Anmission Anchorage BLM General Proc314-3 plugback.doc Swanson River Field UNOCAL9 Well # SCU 314-3 Actual Completion 4/2/89 Tbg Depths are from btm of tbg hgr Tree connection = PBTD =10,798' TD =10,850' MAX HOLE ANGLE = 2° JEWELRY DETAIL NO. TOD Denth Item 0 CASING AND TUBING DETAIL 1 SIZE WT GRADE CONN TOP BOTTOM 22" 10500 Baker 7" DB packer with 10' seal bore 4 Surf 28 11-3/4" 47 J-55 8rd Surf 2,002 7 29 N-80 Buttress Surf 182 7 26 N-80 Buttress 182 1,118 7 23 N-80 Buttress 1,118 4,720 7 26 N-80 Buttress 4,720 5,079 7 29 N-80 Buttress 5,079 8,564 7 29 P-110 8rd 8,564 10,850 Tubing: 3-1/2" 9.2 N-80 BTC AB 0 41 3-1/2" 9.2 N-80 Lock -it 41 10,458 3-1/2" 9.3 J-55 8rd mod 10,466 10,498 2-7/8" 6.5 N-80 Buttress 10,514 10,657 2-1/16" N-80 EUE 8rd 10,662 10,758 JEWELRY DETAIL NO. TOD Denth Item JUL 2 4 2000 Anchorage 0 Tubing hanger w/3-1/2" btc top and bottom 1 10458 Merla 3-1/2" x 1-1/2" TPDX GLM T-2 latch 2 10498 Baker locator and XO, ID = 2.397" 3 10500 Baker 7" DB packer with 10' seal bore 4 10513 XO SBE x 2-7/8" 8rd pin 5 10546 Otis 2-7/8" X nipple, ID = 2.313" 5a 10578 Otis overshot packoff seal, 5.5" OD guide 5b 10582 Top of cut jt of 2-7/8" tbg 6 10594 Baker FH packer 7 10601 Otis 2-7/8" S nipple 8 10634 Camco 2-7/8" MMG GLM w/pup 9 10657 Otis 2-7/8" D nipple 10 10658 Brown Collett Stinger 11 10650 3-1/2" Gravel Flow Packer Liner 12 10791 btm of gravel pack liner JUL 2 4 2000 Anchorage SCU 314-3 schematic.doc REVISED: 06/28/00 DRAWN BY: TAB PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,618 Above H-1 5 8/61 Sqz 10,620 10,625 H-1 4 8/71 Existing 10,629 10,635 H-1 4 8/71 Existing 10,638 10,645 H-2 4 8/71 Existing 10,674 10,684 H-3 4 8/61 Existing 10,708 10,750 H-5 4 8/61 Existing 10,756 H-5 5 8/61 Sqz SCU 314-3 schematic.doc REVISED: 06/28/00 DRAWN BY: TAB Ell UNOCAL Tbg Depths are from btm of tbg hgr Tree connection = Proposed 63-7 Perfs 6155'-6167' DV @ 7980' 1 2 3 4 Proposed 5 Plug 15a 5b 6 10 11 -� 12 PBTD =10,798' TD =10,850' MAX HOLE ANGLE 2° SCU 314-3 prop packerless schematic.doc Swanson Aiver Field Well # SCU 314-3 Proposed Plugback, 8/00 J U L 24 2:00? rt:ga7iLG 1,,.lIs v Ct t�s Coals. 4/�.iillltGis!'3iVl� Anchorage CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" DATE Surf 28 11-3/4" 47 J-55 8rd Surf 2,002 7 29 N-80 Buttress Surf 182 7 26 N-80 Buttress 182 1,118 7 23 N-80 Buttress 1,118 4,720 7 26 N-80 Buttress 4,720 5,079 7 29 N-80 Buttress 5,079 8,564 7 29 P-110 8rd 8,564 10,850 Tubing: Existing 10,638 3-1/2" 9.2 N-80 BTC AB 0 41 3-1/2" 9.2 N-80 Lock -it 41 10,458 3-1/2" 9.3 J-55 8rd mod 10,466 10,498 2-7/8" 6.5 N-80 Buttress 10,514 10,657 2-1/16" H-5 N-80 EUE 8rd 10,662 10,758 8/61 Existing JEWELRY DETAIL NO. Top Depth Item 5 0 Tubing hanger w/3-1/2" btc top and bottom 1 10458 Merla 3-1/2" x 1-1/2" TPDX GLM T-2 latch 2 10498 Baker locator and XO, ID = 2.397" 3 10500 Baker 7" DB packer with 10' seal bore 4 10513 XO SBE x 2-7/8" 8rd. pin 5 10546 Otis 2-7/8" X nipple, ID = 2.313" With proposed PX plug 5a 10578 Otis overshot packoff seal, 5.5" OD guide 5b 10582 Top of cut jt of 2-7/8" tbg 6 10594 Baker FH packer 7 10601 Otis 2-7/8" S nipple 8 10634 Camco 2-7/8" MMG GLM w/pup 9 10657 Otis 2-7/8" D nipple 10 10658 Brown Collett Stinger 11 10650 3-1/2" Gravel Flow Packer Liner 12 10791 btm of gravel pack liner FR' E �U"'E I V" E J U L 24 2:00? rt:ga7iLG 1,,.lIs v Ct t�s Coals. 4/�.iillltGis!'3iVl� Anchorage DRAWN BY: TAB PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6155 6167 Tyonek 63-7 Proposed 8/00 10,618 Above H-1 5 8/61 Sqz 10,620 10,625 H-1 4 8/71 Existing 10,629 10,635 H-1 4 8/71 Existing 10,638 10,645 H-2 4 8/71 Existing 10,674 10,684 H-3 4 8/61 Existing 10,708 10,750 H-5 4 8/61 Existing 10,756 H-5 5 8/61 Sqz REVISED: 07/18/00 DRAWN BY: TAB STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COM..ASSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate _ Plug iLn Perforate — ReWm to Prod. Pull tubing After casing Repair well Pull tubing Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development x UNION OIL COMPANY OF CALIFORNIA UNOCAL Exploratory _ Stratigraphic _ 149' RKB feet 3. Address 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM SCU 314-3 9. Permit nu be ? At top of productive interval Same as above ORIGINAL 10. API number At effective depth Same as above 50-133-1010-00 11. Field/Pool At total depth Same as above Swanson River/Hemlock •-. 12. Present well condition summary L 1 e ,. Total depth: measured 10,850' feet Plugs (measured) 10,798' true vertical 10,848' feet OCT 2 Effective depth: measured 10,798' feet Junk (measured) true vertical 10,796' feet NaSM.Oil & Gas Cons. COMMISS k ,anchorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22" Yes 28' 28' Surface 2,002' 11-3/4" 1350 sx 2,002' 2,002' Intermediate Production 1000' -' . T' - 700 sx Ist Stage 10,850' 10,848' 1,200 sx 2nd Stage Liner Perforation depth: measured 10,620-10,625'; 10,629-10,635'; 10,638-10,645'; 10,674-10,684'; 10,708-10,750' true vertical 10,618-10,623; 10,627-10,633'; 10,636-10,643; 10,672-10,682'; 10,706-10,748' Tubing (size, grade, and measured depth) 3-1/7, 2-7/8", 2-1/16', N-80, tbg with tail to 10,758'. Packers and SSSV (type and measured depth) Baker'DB' packer @ 10,500', Baker'FH' packer @ 10,594' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Data Tubing Pressure Prior to well operation Inject (June, 1994) --- 43,200 -- 990 4690 Subsequent to operation Produce (9/6/95) 0 17,437 2 1325 2500 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run *See Below Daily Report of Well Operations Oil X Gas Suspended Service 17. 1 hereby certify that the foregoin is a and correct to the best of my knowledge. 10/2910 Signed D. L. Groboske Title Petroleum Engineer Date Form 10-404 Rev 06/15/88 " -j/V bUCMI 1 1N uuruurlI r- *SCU 314-3 was taken out of Hemlock gas injection service in July, 1994 and is currently an intermittent Hemlock Producer. STATE OF ALASKAL° ALASK'IL AND GAS CONSERVATION CCAISSION REPORT OF SUNDRY WELL OPOIATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Perforate — Pull tubing _ After casing_ Repair well _ Pull tubing _ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal Development KB: 149' _ E*oratory ft"gr phtc _ feet 3. Address 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 service X__ Soidotna Creek Unit 4. Location of well at surface 8. Well number 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM SCU 314-3 9. Permit number/approval number At top of productive interval RECEIVED 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM 61-23 10. API number At effective depth APR 2 2 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM 1gg� 50-133-10100-00 11. Field/Pool At total depth Alaska Cii & Gas Cons. Commission 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM AnGherege Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10850 feet Plugs (measured) ORIGINAL true vertical 10848 feet Effective depth: measured 10798 feet Junk (measured) true vertical 10796 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22 Yes 28' 28' Surface 2002' 11-3/4' 1350 sx 2002' 2002' Intermediate Production 10850' 7' 1900 sx 10850' 10848' Liner Perforation depth: measured 10620-10625,10629-10635,10638-10645,10674-10684,10708-10750 true vertical 10618-10623,10627-10633,10636-10643,10672-10682,10706-10748 Tubing (size, grade, and measured depth) 3-1/2, 2-7/80,2-1/160, N-80 @ 10758' Packers and SSSV (type and measured depth) Baker 'DB' pkr. @ 10500', Baker'FH' pkr. @ 10594' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes.used and final pressure 14. Representative Daily Average Production or Iniection Data Oil—Bbl Gas—Mcf Water—Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run_ Daily Report of Well Operations X Oil Gas Suspended _ Service Water injector _ 17.1 hereby certify that the going is true and correct to the best of my knowledge. L4j ILL i �. � ��.CP�. Date Signed Title Form 10=404 Rev 06/15/88 SUBMIT IN DUPLICATE 0 - UNOCAL � WELL SERVICE REPORT REMARKS: ul v _ f 4p :► WEATHER EMP. HILL FACTOR ISIBIUTYIND VEL NITIALS: REPORT F F mL kts.DOM i V .i :I I A iI ... WEATHER EMP. HILL FACTOR ISIBIUTYIND VEL NITIALS: REPORT F F mL kts.DOM PAGE OF STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Lf A2 p C A� FIELD / UNIT 1 PAD: SW J4x)S�ti1 t VE'Q FI�!.� S C lJ DATE: WELL NAME *P *S *N TYPE ANNULUS FLUID PACKER TVD MD CASING SIZE ! WT 1 GRADE TBG SIZE REQ TEST PRESS PRETEST TBG CSG PRESS START TIME TBG CSG PRESS 15 MIN TIME TBG CSG PRESS 30 MIN TIME TBG CSG PRESS START TIME P I F M = MISCIBLE INJ. � � PQ offa c � 'VA i o S" 7 � .S'7 Sa S'7C"v N = NOT INJECTING � =OTHER ry .4133, CD ;n OTHER COMMENTS: 3,R,1- 3 was 7 .��` - o ong - Well File S7 S" O S"o 15" 7sZ� as'� �,�,-© so 3 o a o 3 P I --- ,n s� COMMENTS 31-Y-3 17 -23. Al -8o �az loot Sr OPERATOR REP SIGNATU c - Trip Rpt File t o v oo COMMENTS: c - li Kpectc r COMMENTS' COMMENTS: , vo -TUBING INJECTION FLUID: ANNULAR FLUID: GRADIENT: WELL TEST: P = PRODUCED WATER INJ. o A 1"�, DIESEL r Initlal� S = SALT WATER INJ GLYCOL � 4 - Years_ M = MISCIBLE INJ. � � � n • SALT WATER Wotkover I = INJECTION o r" DRILLING MUD tither - N = NOT INJECTING � =OTHER ry .4133, CD ;n OTHER Distribution: 3 z 0a ong - Well File 3, AOGCC REP SIGNATURE c - Operator c - Database G OPERATOR REP SIGNATU c - Trip Rpt File FI4051.XLT (Rev. 12192) ' c - li Kpectc r J STATE OF ALASKA cx7 ALASK AND GAS CONSERVATION COMA4fSSION APPLIC' ,ON FOR SUNDRY APS OVALS zpj,,., J� 1. Type of request: Abandon _ Suspend ` Operations shutdown ` Re-enter suspended well— Mer casing` Repair well Plugging , Time extension , Stimulate _ Change approved program �. Pull tubing — Variance Perforate _ OtherX_ (MIT) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of Califomla (Unocal) Development 149' KB , Exploratory _ -%aNrepw — feet 3. Address 7. Unit or Property name P.O.Box 196247 Anchorage, Alaska 9%19-6247 servloe X Soldotna Creek UMt 4. Location of well at surface 8. Well number F T7N, R9W, SMRECEIVED LI 314-3 Permit 9. number At top of productive,Interval Same as Above '9 At effective depth J U L 2-0 1993 10. API number Same as Above Commission 50-133-10100-00 11. Field/Pool At total depth .Alaska 011 & Gas Cons. Same as Above Anchorage Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10850 feet Plugs (measured) true vertical 10648 feet Effective depth: measured 10798 feet Junk (measured) true vertical 10796 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22' Yes 28' 28' Surface 2002' 11-3/4' 1350 ex 2002' 2002' Intermediate Production 10850' 7' 700 sx 1 st stage 10850' 10848' i Zoo ax srw singe Liner Perforation depth: measured 10620-10625,10629-10635,10638-10645,10674-10684,10708-10750 true vertical 10618-10623,10627-10633,10636-10643,10672-10682,10706-10748 Ting (size, grade. and measured depth) 3-1/20, 2-7/8', 2-1/160, N-80 tubing with tail @ 10758' Packers and SSSV (type and measured depth) Baker 'DB' p1w. 0 10500' Baker'FH' pkr. 0 10594' 13. Attachments Description summary of proposal ! Detailed operations programX _ BOP sketch _ 14. Estimated date for commencing operation I& Status of well classification as: July 21, 1993 Oil— Gas Suspended 16. if proposal was verbally approved Name of approver Date approved Service LnLeStor 17.1 here art that t i is t correct to the best of my knowledge. t kt, Uri ck ` ktWxc-K Signed Tftie ` Date v Lk" FOR COMMISSION USE ONLY Conciltfons of approval: Novy Commission so represerdadw may witness Approval No. J Plug Integrity BOP Te _ Location clearance _ - /& Mechanical Integrity Test,," Subsequent required 10- -- 1l Approved Copy Returned 12a Original 31gned By Approved the order of the Commission David W. Johnston Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PC & SC Loading and PC Pressure Test SCU 314-3. SR 44 Objective: To load the PC and SC and verify mechanical integrity on the PC for the AOGCC monitored MIT. Well Data: Thg. PC: SC: Top pkr. depth: Capacities: Current Pressures: Procedure: 3-1/2" EUE tbg. to 10, 513' MD 7" N-80; 23, 26 and 29# to 10,850' MD 11-3/4" 47# J-55 to 2,002' MD 10, 500' MD Tbg x PC = .0264 Bbls/ft. PC x SC = .0699 Bbls/ft. Tbg = 4900 psi; PC = 730 psi; SC = 0 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 1% W M76 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 20 1993 Alaska Oil & Gas Cons. Commission Anchorage PC & SC Loading and PC Pressure Test SCU 314-3, SR44 Page Two NOTE: Contact the AOGCC (279-1433) and BLM (267-1222) at least 24 hours prior to performing the PC pressure test. 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. If less than 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. 12. Repeat step #I I until 3690 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. 13. RDMO. REE E IV ED J U L 2 0 1993 Alaska oil & Gas Cons. Cornmissic;` Anchorage Alaska Inc. - Swanson Rives ,Id SCU 314-3 u _ .Pi#: 133-10100-00 Neil Type: Gas Inj. Spud Date: 6/16/61 Completion Date: 8/61 Last Workover:4/2/89 Original RKB: 149' Hanger Type: Shaffer Hanger: Top of Hemlock: 10620' Max. Hole Angle: 20 Angle @ Hemlock : 21D All Depths are RKB MD to Top of Equipment. Jewelry Casing and Tubing 1 5 1 10,458 Mersa 3-1/2"xt-1/2" TPDX GLM T-2 Latch I 10,620- 10,625 Grade I" aQtf4f]I0. 2 10,498 Baker Locator and X -O I. D. 2.397 10,629- 10,635 H1 0 28' 3 10,500 Baker 7" Model "DB" Packer w/ 10' Seal Bore 47# J-55 0 2002' 4 10,513 X -O SBE x 2-7/8" 8RD Pin 29# N-80 0 182' 5 10,546 Otis 2-7/8""X" Nipple I. D. 2.313 26# N-80 182' 1118' 6 10,594 Baker 7" Fit Packer 23# N-80 1118' 4720' 7 10,601 Otis 2-7/8" "S" Nipple 26# N-80 4720' 5079' 8 10,634 Can -co 2-7/8" MMG GLM w/pup 29# N-80 5079' 8564' 9 10,657 Otis 2-7/8" "D" Nipple 29# P-110 8564' 10,850' D.V. 7980' 10 10,658 Brown Collet Stringer 9.3# N-80 0 I 11 3-1/2" Gravel Flow Packer Liner 1 Minimum ID: 1.751" below 10662' (2 1/16" tbg� Casing and Tubing 1 5 2 Size Weight I 10,620- 10,625 Grade I" aQtf4f]I0. 3 22" 10,629- 10,635 H1 0 28' 113/4" 47# J-55 0 2002' 4 7" 29# N-80 0 182' 5 7" 26# N-80 182' 1118' 7" 23# N-80 1118' 4720' 5 7" 26# N-80 4720' 5079' 7" 29# N-80 5079' 8564' 7 7" 29# P-110 8564' 10,850' 3-1/2* 9.3# N-80 0 41' B 3-1/2" 9.3# N-80 41 10,458' 3-1/2" 9.3# J-55 10,466' 10,498' 2-7/8" 6.5# N-80 10,514' 10,657' 2-1/16" 6.5# N-80 10,662' 10,758' 9 Perforation Data 10 Interval Zone Description Structural Surface Casing Production Casing Production Casing Production Casing Production Casing Production Casing Production Casing BTC AB -Mod Tbg Lock-itTubing AB -Mod Tbg Tubing Tubing EI SE Date QQrn m ant s 10,618 Above H1 1 5 8/61 I 10,620- 10,625 H1 5 4 8/71 10,629- 10,635 H1 6 4 8/71 10,638- 10,645 H2 7 4 8/71 10,674 - 10,684 H3 10 4 8/61 10,708 - 10,750 H5 42 4 8/61 10,756' H5 1 5 8/61 PBTD = 10,798' TD = 10,850' Cmt. Sqz. Cmt. Sqz. Well scu 3,a�ECEIV JLB 5/15/89 J U L 20 1993 Alaska Oil .& Gas Cons.,GufnfnissOl Anchorage ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL #343 TO: John Boyle FROM: Tom Wellman COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: Aug. 22, 1989 WELL NAME: Listed Below Transmitted herewith are the following Blue Sepia Sepia Line olded Rolled M lar Ta Gamma Ray SCU 41-9A 1 PLS SCU 41-9A 1 Vertilo SCU 14-3 1 Vertilo SCU 31-8 1 Receipt Acknowledgement: Return reciept to ARCO ALASKA, Inc. ATTN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Da `- 2 Alaska OIC$ 'fig C0n£ C01flRJISSIC Androtage ARCO Alaska, Ir" Post Offic_ fa,. 100360 ` 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 99601 Re: Initial MIT of SCU 314-3 Dear Mr. Chatterton: Attached are Sundry Notice and Well Service Report which document the initial production casing pressure test on gas injection well SCU 314- 3. The well was tested in accordance with Rule 6 of the AOGCC Area Injection Order No. 13. The well held its required test pressure (within 10%) for 30 minutes. This pressure test will serve as the well's initial UIC test for a Class II well. Please contact Stacy Strickland at 263-4914 if you have any questions concerning this matter. Sin erely, . g. `i,Z!:�4. T. S. McCorkle. TSM:DML:ch:0003 Attachments cc: G. A. Graham UNOCAL Corporation A. R. Kukla Marathon Oil Company VEL) Alf ic 0 13ska o#& Gas Cons ° nmiss on ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR313-6279 • ° %-� STATE OF ALASKA ^: OIL AND GAS CONSERVATION CON. N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown - Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing Repair well _ Pull tubing Other X M I T 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development_ 149' RKB feet Exploratory _ Stratigraphic7. Service _' 3. Address P. 0. Box 100360 Anchorage, AK 99510 Unit or Property name So I dotna Creek Unit 4. Location of well at surface 8, Well number 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM SCJ 314-3 9. Permit number/approval number At top of productive interval Same as above. 10. API number At effective depth Same as above. 50— 133-1010-00 At total depth 11. Field/Pool Same as above. Swanson River -Hemlock 12. Present well condition summary Total depth: measured 10, 850' MD feet Plugs (measured) 10,7981 PBTD true vertical 10,8481 TVdeet Effective depth: measured 10,7981 MD feet Junk (measured) true vertical 10,7961 TVCfeet None Casing Length Size Cemented Measured depth True vertical depth Conductor 28' 22" yes 28' MD 28' TVD Surface 2,002' 11-3/4" 1350 sx 2,002' MD 2,002! TVD Production 10,8501 7" 700 sx 1st stage 10,8501 MD 10,8481 TVD X2&er 1,200 sx 2nd stage Perforation depth: measured 10,620-10,6251 ; 10,629-10,6351; 10,638-10,6451 ; 10,674-10,6841; 10,708-10,750'. true vertical 10,618-10,623'; 10,627-10,6331; 10,636-10,643'; 10,672-10,6821; 10,706-10,7481. Tubing (size, grade, and measured depth) 3-1/211, 2-7/811, 2-1/1611, N-80, tbg with tail to 10,7581. Pgckersano, �SV(tyCKer rr�ea)S�re i�l��th) Baker ' FH' packer 10, 594' . aker D Pac er y 13. Stimulation or cement squeeze summary .q Intervals treated (measured) A,, k." N/A Treatment description including volumes used and final pressure `f -_ 11 I.i as GuIIS. "V:rl ` _ - Arjohoraqq 14. Representative Daily AverageXMMWn or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation -- 34,491 -- 270 5,320 Subsequent to operation -- 34,841 -- 375 4,700 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Gas Injector Daily Report of Well Operations.._ Oil _ Gas _ Suspended _ Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ��� Title Cook Inlet Engineering Manager Date Z 2P2 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL ARCO Alaska, lnc�> Subsidiary of Atlantic Richfield Co' IPBOT o 3\4 - REMARKS FIELD - DISTRICT - STAT Kw OPERATION AT REPORT TIME k � �� C 'WELL SERVICE REPORT DAYS IDATE z 400 Pow? -z-v%x-v- [AOL -ID � 4SAT-En�:!1 AA60 — k,500 (!Q&Z0C:TS1D MM -T Pt -5 7—*CL.A ^1&254. 1 140c) (0 JAJ I a IS 0 —.JI I Ll 41IM(oo- Swo 14 /4G -)O ?qs-o 14A�30 �(6oa-- 307 14 C-) las4tt-') So )444ir 8 toll o 1600 SCA o tSots -- L�5-4S-' CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherTemp. Rel: I Chill Factor I Visibility OF I OF! miles -b.laska Oil & Gas Com Gomm issi0l.' Avichorage (Clibse'r-z' Wind Val. knots Slgned-t'71-'� .'UL b'-- 14: 3-.� IV: bWHIN=jUll N i Vr-M'.ILL llu- *C�tj oo,06 . ..... ..... . ............ .777300 2500, ...... 40 2000; 00 000 so tA do 09-4000 O -T V -o all CIA or St IDIV t"t'j, 0 09 000 ......... . 9 : IF \ . % , 1, f lid 017S cs ell ALASKA OIL AND GAS C MERVATION CU' 1BSION MhC TICAL INTEGRM TM ----------- IJato: C Tang= Field:'.. pm7m STAN 15 HIN 30 MIN *p *I 1 Yt,E OF PKR CASING TBG REQ TBG TDE Tl IE �1E WELL *S. ---- ANiUU5 TVD SIZE/Wr/GME SIZE TEST CSG TBG TEG I73G c(Iltu s *lei *N FWLD MD PRESS PRESS CSG CSC CSG PRFSS PRFSS PRESS *UMItK; 1JUE 'TI0H FLUID: AtIA) .AR FLUID: P PRODUCE WAIIR UU DIESEL S SALT WAlM Ltd GI ODL M HISCIBIE INJ CrION SALT WATER I IN FCT7jG DRILLING tUD ,. N • NUT INTELTIM an MR 4709 4- - OTR ', :00- 1 -3 1. /1-5-o", GRADIF.UT: via f A= wnmo s-iTjp+ SISINS '!' 'OIL" 20 MC 25.030(a) 20 MC 25.412€c? - 20 AAC 25.252{d} 7 R R 2 c u U x R R G G ARCO Alaska, Inc.' Post Office Bak 100360 A chorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures May 19, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Initial MIT of SCU 14-3 Notice of Name Change Dear Mr. Chatterton: ,pR��INqJ`� ,oc Written approval of the attached MIT procedure is requested for SCU 14-3. The procedure is designed to demonstrate this well's tubing/production casing integrity to comply with Area Injection Order No. 13, Rule No. 6. It will serve as this well's initial UIC test for a Class II well. Note that verbal approval to perform this test was granted by Mike Minder on May 19, 1989 (Ref: phone conversation with Carol Baker). In addition, the attached Sundry will serve to notify you of this well's name change. In order to comply with the field standards, SCU 14-3's name will be changed to SCU 314-3 as it has been converted from producer to injector. Plans are to perform the recommended testing as soon as possible. Please contact Carol Baker at 263-4643 if you have any questions concerning this matter. Sincerely, T. S. McCorkle TSM:CMB:ch:0016 Attachment cc: G. A. Graham UNOCAL Corporation A. R. Kukla Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED MAY 2 3 1989 Alaska Oil & Gas can Commission Anc110reSle ARSB -6279 ARCO Alaska, Inc. Post Office Box 1`00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures May 19, 1989 Mr. C. V. Chatterton, Chairman .Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Initial MIT of SCU 14-3 Notice of Name Change Dear Mr. Chatterton: �!Zrp- 41 ..fir-33 ; - C Written approval of the attached MIT procedure is requested for SCU 14-3. The procedure is designed to demonstrate this well's tubing/production casing integrity to comply with Area Injection Order No. 13, Rule No. 6. It will serve as this well's initial UIC test for a Class II well. Note that verbal approval to perform this test was granted by Mike Minder on May 19, 1989 (Ref: phone conversation with Carol Baker). In addition, the attached Sundry will serve to notify you of this well's name change. In order to comply with the field-. standards, SCU 14-3's name will be changed to SCU 314-3 as it lam"` has b a been converted from producer to injector. Plans are to perform the recommended testing as soon as possible. Please contact Carol Baker at 263-4643 if you have any questions concerning this matter. Sincerely, RECEIVED d' MAY 2 3 1989 T. S. McCorkle Alaska 411 & Gas C011s. "M180011 TSM: CMB: ch:0016 Anchl)HWO Attachment cc: G. A. Graham UNOCAL Corporation A. R. Kukla Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichiieldCompany AR38-6279 STATE OF ALASKA AL, .:A OIL AND CAS CONSERVATION COMMIStiON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _.. Operation shutdown _ Re-enter suspended well— Mec h a n i ca I I n to gg r i t Stimulate & Name C h a n g Alter casing _ Repair well Change approved program — — Plugging _ Time extension _ _Test Pull tubing _ Variance _ Perforate _ Other _X_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development_ Exploratory _. Stratigraphic _ 149' RKB feet 3. Address 7. Unit or Property name P. 0. Box 100360 Anchorage, AK 99510 Service _X. So I dotna Creek Unit 4. Location of well at surface 8. Well number SCU 14-3 (01 d Ne i 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM SCU 314-3 (New Name) 9. Permit number At top of productive interval Same as above. 10. API number At effective depth Same as above. 50-133-1010-00 At total depth 11. Field/Pool Same as above. Swanson River - Hemloc 12. Present well condition summary Total depth: measured 10,8501 MD feet Plugs (measured) 10,7981 PBTD true vertical 10, 848' TVD feet Effective depth: measured 10, 798' MD feet Junk (measured) None true vertical 10, 796' TVD feet Casing Length Size Cemented Measured depth True vertical depth NKXKW4 Conductor 281 22" Yes 28' MD 28' TVD Surface 2,002' 11-3/4" 1350 sx 2,002' MD 2,002' TVD 1X%XWbW&e Production 10,8501 7" 700 sx 1st Stage 10,8501 MD 10,8481 TVD Liner 1,200 sx 2nd Stage Perforation depth: measured 10,620-10,6251 ; 10,629-10,6351; 10,638-10,6451; 10,674-10,6841; 10,708-10,7501. truevertica110,618-10,6231; 10,627-10,633'; 10,636-10,6431; 10,672-10,6821; 10,706-10,7481. Tubing (size, grade, and measured depth) 3-1/2"/2-7/8"/2-1/16", N-80, tbg with tail to 10,7581. Packers and SSSV (type and measured depth) Baker 'DB' packer Q 10,5001, Baker 'FH' packer a 10,5941. 13. Attachments Description summary of proposal _ Detailed operations program _ BOP sketch_. RECH FD 14. Estimated date for commencing operation 15. Status of well classification as: 5/20/89 MAY 23 190 Oil — Gas _ Suspended 16. If proposal was verbally approved Oil & Gas COns. MM Name of approver Date approved Service Gas Injection 'ect i on Alaska C11= 6 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed l/ Title Cook Inlet Engineering Manager Date S %4 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity _ BOP Test _ Location clearance Mechanical Integrity Test _ Subsequent form required 1_0- 611" Apr,-r,i/- to Copy ORIGINAL SIGNED BY Returned _- ra Com loner Date Approved by order of the Commissioner ,,. L C. SMITH Form 10-403 Rev 06/15/88 !v SUBMIT IN TRIPLICATE ne) ssion �i Objective: Well Data: PC & SC Loading and PC Pressure Test SCU 314-39 SR 44 To load the PC and SC and verify mechanical integrity on the PC for the AOGCC monitored MIT. Tbg: PC: SC: Top pkr. depth: Capacities: Current Pressures: Procedure: Load PC and SC 3-1/2" EUE tbg. to 10, 513' MD 7" N-80; 23, 26 and 29# to 10, 850' MD 11-3/4" 47# J-55 to 2,002' MD 10, 500' MD Tbg x PC = .0264 Bbls/ft. PC x SC = .0699 Bbls/ft. Tbg = 4900 psi; PC = 730 psi; SC = 0 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 1% WT676 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). ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6101-A RECEIVED SAY 2 3 1989 pil Gas Cons. Commission A1Anchorage y `�*. r PC & SC Loading and PC Pre SCU' 314-3, SR44 press Test Page Two NOTE: Contact the AQGC hours prior to C (279-1433) and .BLM performing the PC pressure t 267-12221 at least 24 PC Pressure Test est. 10• Pressure minimum up PC to 500 psi over 1 Hold far five current pressure pressures), minutes (observing tbb•, PC ,000 psi and SC 11. If less than 50 psi is Psi- Hold for eve ruin Inst in five minutes, increase ase pressure by 500 12. Repeat step #11 until 3690 minutes, noting initial andfinal psi is reached. pressures on all old pressure for 30 13. RDMO. strings. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3e-6oaf-A RECEIVED MAY 2 3 1989 Alaska Oil & Gas Cons. COmmiSSWO AoftM S Alaska Inc. - Swanson River**Id 111 Q11- SCU 314-3 -%eel#: 133-10100-00 Well Type: Gas Inj. Spud Date: 6/16/6-i Completion Date: 8/61 Last Workover:4/2/89' Original RKB: 149' Hanger Type: Shaffer Hanger: Top of Hemlock: 10620' Max. Hole Angle: 20 Angle @ Hemlock : 20 All Depths are RKB MD to Top of Equipment. Jewelry 1 it •- ., �.. •. l Casing and Tubing 1 10,458 Meda 3-1/2"x1-1/2" TPDX GLM T-2 Latch 2 Size Weight 2 10,498 Baker Locator and X -O I.D. 2.397 j -R Bottom Description 3 10,500 Baker 7" Model "DB" Packer w/ 10' Seal Bore 0 4 10,513 X -O SBE x 2-7/8"8131) Pin Structural 113/4" 47# 5 10,546 Otis 2-7/8" "X" Nipple I.D. 2.313 0 2002' Surface Casing 6 10,594 Baker 7" Fit Packer 29# N-80 0 7 10,601 Otis 2-7/8" "S" Nipple Production Casing 5 7" 26# 8 10,634 Camco 2-7/8" MMG GLM w/pup 182' 1118' Production Casing 9 10,657 Otis 2-7/8" "D" Nipple 23# N-80 1118' D.V. 7980' 10 10,658 Brown Collet Stringer Production Casing 5 7" 26# 11 3-1/2" Gravel Flow Packer Liner 1 it •- ., �.. •. l Casing and Tubing 2 Size Weight Grade j -R Bottom Description 3 22" 0 28' Structural 113/4" 47# J-55 0 2002' Surface Casing 4 7" 29# N-80 0 182' Production Casing 5 7" 26# N-80 182' 1118' Production Casing 7" 23# N-80 1118' 4720' Production Casing 5 7" 26# N-80 4720' 5079' Production Casing 7" 29# N-80 5079' 8564' Production Casing 7" 29# P-110 8564' 10,850' Production Casing 3-1/2" 9.3# N-80 0 41' BTC AB -Mod Tbg 3 3-1/2" 9.3# N-80 41' 10,458' Lock-itTubing 3-1/2" 9.3# J-55 10,466' 10,498' AB -Mod Tbg 2-7/8" 6.5# N-80 10,514' 10,657' Tubing 2-1/16" 6.5# N-80 10,662' 10,758' Tubing 9 Perforation IO Data Interval Zone f -I SPF Date Comments 10,618 Above H1 1 5 8/61 Cmt. Sqz. 1 10,620- 10,625 1-11 5 4 8/71 10,629- 10,635 1-11 6 4 8/71 10,638- 10,645 H2 7 4 8/71 10,674- 10,684 H3 10 4 8/61 10,708 - 10,750 H5 42 4 8/61 10,756' H5 1 5 8/61 Cmt. Sqz. PBTD = 10,798' TD 10,850' RECEIVED II SCU 314-3 = JLB 5/15/89 SAY 2 31989 Gas Cons. emission. Alaska OU & mohotage E-Lme BOPE I s ..._— Grease Head/ Hydraulic Packoff .-- Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead RECEIVED MAY 2 3 1989 Alaska oil & Gas Cons. C°mmissiotl Anchorage STATE OF ALASKA - ` ALASKA OIL AND GAS CONSERVATION COMMISSION W9LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL GAS ❑ SUSPENDED U ABANDONED ❑ SERVICE © Classification of Service Well Gas Iniector 2. Name of Operator ARCO Alaska, Inc. 7. Permit Number 23-6t" 6 1 - 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 8. API Number 50_ 133-1010-00 4. Location of well at surface 650' FSL, 690' FWL, Sec. 3, WN, R9W, SM At Top Producing Interval 650' FSL, 690' FWL, Sec. 3, WN, R9W, SM At Total Depth 650' FSL, 690' FWL, Sec. 3, WN, R9W, SM 9. Unit or Lease Name Soldotna Creek Unit 10, Well Number SCU 14-3 1 1 . Field and Pool Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) RKB 149' 6. Lease Designation and Serial No. A-028997 12. Date Spudded 06/16/61 13. Date T.D. Reached -- 14. Date Comp., Susp. or Aband. 08/02/61* 15. Water Depth, if offshore N/A feet MSL 16. No, of Completions 1 17. Total Depth (MD+TVD) 10850'MD&TVD 18.PIug Back Depth (MD+TVD) 10798'MD&TVD 19. Directional Survey YES © NO ❑ 20. Depth where SSSV set Non& -et MD 21. Thickness of Permafrost --- 22. Type Electric or Other Logs Run DIL., BHCS, Microlog/Cal, Dipmeter, CBL, GR/CNL, WSO, Gyro, Vertilog 23, CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" -- -- Surf 28' -- -- 11-3/4" -- -- Surf 2002' -- 135 7" -- -- Surf 10850' -- 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Perforated w/4 spf 10620'-10625'MD/TVD 10629'-10635'MD/TVD 10638 '-10645 'MD/TVD 10674 '- 10684 'MD/TVD 10708'-1 0750,"'MD/TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NA 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL -BSL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY -API (corr) 28, CORE DATA Brief description of Iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A E C �,� a >., tw * Note: Workovers performed 12/01/62, 08/17/71 & 04/02/89. :t {!PJa" Jiaet Form 10-407 0 4 0 / W C6 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 0 N/A 31. LIST OF ATTACHMENTS None 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed TitleArea Drilling Engr. INSTRUCTIONS Date - D General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (QF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other -explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging — Perforate _ Pull tubing _V_ Alter casing _ Repair well _ Other -V Wo rkover 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development — Exploratory _ Stratigraphic _ RKB 149' feet 3. Addr ss 7. Unit or Property name P.�. Box 100360 Anchorage, AK 99510-0360 Service.' Soldotna Creek Unit 4. Location of well at surface 8. Well number SCU 14-3 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM 9. Permit number/approval number At top of productive interval 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM 91 -91/8 -An? - - 10. API number At effective depth At 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM 50 133-1010-00 11. Field/Pool At total depth 650' FSL, 690' FWL, Sec. 3, T7N, R9W, SM Swanson River -Hemlock 12. Present well condition summary Total depth: measured 108501MD feet Plugs (measured) None true vertical 10850' TVD feet Effective depth: measured 10798' MD feet Junk (measured) None true vertical 107981TVD feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22" -- 281MD 281TVD Surface 2002' 11-3/4" 1350 sx 20021MD 20021TVD Intermediate 10850' 7" 1900 sx 108501MD 10850'TVD Production Liner Perforation depth: measured 106201-106251, 106291-106351, 106381-106451 106741-106841, 107081-10750' true vertical 106201-106251., 106291-106351, 106381-106451 106741-106841, 107081-10750' Tubing (size, grade, and measured depth) 3-1/211/2-7/811, N-80, tbg w/tail @ 10758' RECEIVED Packers and SSSV (type and measured depth) Baker 'DB' pkr @ 105001, & Baker 'FH' pkr @ 10594' 13. Stimulation or cement squeeze summary N/A Alaska.0i1 & Gas Cons. Commisslort Intervals treated(measured)i i Anchoraga Treatment description including volumes used and final pressure 14. . Representative Daily Average Production or Injection Data N/A Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _L \�Oii _ Gas _ Suspended _ Service Cac n rtnr 17. 1 hereby certify that the foregoing is true and correct to the est of my knowledge. Si ned TitLe_'Area Drillina Enar. Date Form 10-404 Rev 06/15/88 *Workover Well History (DAM) SW04/031 SUBMIT IN DUPLICATE 0 R e ARCO Oil and Gas Company „ Well History - Initial Report - Daily Instructions: Prepare and submit the "initial Rawl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District County, parish or borough State ARCO ALASKA INC. COOK INLET/KENAI AK Field Lease or Unitell no. SWANSON RIVER ADL: A-028997 SCU 14-3 W Auth. or W.O. no. Title AD6251 WORKOVER API: 50-133-1010-00 Operator ARCO W.I. ARCO 48.4864 Spudded or W.O. begun Date Hour Prior status it a W.O. ACCEPT 03/26/89 1600 Date and depth Complete record for each day reported as of 8:00 a.m. ROLL' N RIG 5 03/26/89 ( ) TD:10850 PB:10798 SUPV:EEV 03/27/89 ( ) TD:10850 PB:10798 SUPV:EEV 03/28/89 TD:10850 PS: 10798 SUPV:EEV 03/29/89 TD:10850 PB:10798 SUPV:EEV 03/30/89 ( ) TD:10850 PB:10798 SUPV:EEV 03/31/89 ( ) TD:10850 PB:10798 SUPV:EEV The above is correct Sign r For form pre tion and distrlb see Procedu tinual, Section , Drilling, ,..E% eg 86 and 87. AR3B-459-1-D RIGGING UP MW: 8.8 NaCl CONTINUE RIGGING UP. WAITING ON NEW CROWN SHEAVE. INSTALL NEW CROWN SHEAVE. SITP 175 AND SICP 575 PSI. DAILY:$4,615 CUM:$27,075 ETD:$27,075 EFC:$360,000 N/U BOP'S MW: 8.8 NaCl SHOT FLUID LEVEL: TBG 8 621' W/ 160PSI. CSG 8 1674' W/ 600 PSI. TESTED 7" CSG PACK—OFF TO 3000 PSI. SEALS ON TUBING HANGER LEAKED FROM 5000 TO 3000. FIN R/U RIG. RAISED DERRICK. TESTED CIRCULATING LINES TO 2600 PSI. CIRC 8.8PPG BRINE DOWN TUBING TAKING RETURNS FROM ANNULUS. SHUT IN CASING SIDE AND ATTEMPT TO TEST CASING. CASING BLEED FROM 150OPSI TO 400 PSI IN 5 MINUTES. OPEN WELL AND BREAK CIRCULATION. OBSERVE WELL FOR 1 HOUR..LOST 3 BELS. CBU. OBSERVE FOR 1 HOUR..LOST 3 BBLS. SET BPV AND N/D TREE. N/U SPACER SPOOL AND BOP'S. ****ACCEPTED RIG AT 1600 HR 3/26/89**** DAILY:$7,000 CUM:$34,075 ETD:$34,075 EFC:$360,000 POOH WITH TUBING MW: 8.8 NaCl FILL HOLE WITH 14 BBL BRINE. RAISE SUB AND RIG UP RIG FLOOR. TEST BOP'S. PULL HANGER WITH SOME DIFFICULTY. POOH WITIt TUBING. DAIZIY:$16,970 CUM:$51,045 ETD:$51,045 EFC:$360,000 POOH W/ RTTS MW: 8.8 NaCl FINISH POOH,PU RTTS AND STRAP IN,BOP DRILL,STRAP IN HOLE,RIG SERVICE,FINISH TIH,SET RTTS AT 10534,LOST 34 BBLS OVER DISPLACEMENT,NO RETURNS,CLOSE PIPES RAMS,TEST CSG TO 3000 FOR 30 MIN,PUMP DOWN TBG,PRESSURE INCREASED TO 500,SHUT DOWN AND BLEED TO ZERO,RELEASE RTTS,CBU,CDL,POOH,LOST 40 BBLS OVERDISPLACEMENT DAILY:$45,646 CUM:$96,691 ETD:$96,691 EFC:$360,000 CHANGE OUT TUBING HEAD MW: 8.8 NaCl POOH WITH RTTS. R/U DRESSER ATLAS AND RUN VERTILOG FROM 10,493' TO SURFACE. CASING APPEARS TO BE IN GOOD CONDITION. R/D DRESSER. P/U RBP AND RIH. SET AND AT 10500. SET STORM PLUG AND TEST TO 500 PSI. N/D BOP AND CHANGE OUT TUBINGS. DAILY:$31,956 CUM:$128,647 ETD:$128,647 EFC:$360,000 RPOH W/ OS MW: 8.8 NaCl NII 11" — 3000 PSI X 7-1/16" — 5000 PSI TBG HEAD. TEST PACK OFF TO 3000 PSI. NU ROPE. TEST TO 5000 PSI. RU FLOW LINE. RELEASE STORM PKR. LD SAME. RIH AND RELEASE RBP. CBU. POOH W/ RBP. MU 5-3/4" OS W/ 2-7/8" ID MILL CONTROL W/ PACK _j Date Title DAR* Supt. RECEIVED �f )" _1 Number all daily well history forms consecutively Page no. as they are prepared for each well. Alaska Oil .& Gas Cons. Ccmmissi� Anchorage ARCO Oil and Gas Company „ Daily Well History—Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish State ARCO ALASKA INC. COOK INLET/KENAI AK Field Lease or Unit Well no. SWANSON RIVER SCU 14-3 Date and depth 8:00 a.m. Complete record for each day while drilling or workover in progress as of ROLL' N RIG 5 04/01/89 ( 9) POH L/D WORK STRING MW: 8.8 NaCl TD:10850 POOH WITH TRISTATE OVER SHOT. MAKE UP OTIS 0/S PACK—OFF AND PB:10798 TAIL PIPE ASSY MAKE GUIDE FOR O/S PACK—OFF. RIH W/ 0/S SUPV:DL PACK—OFF AND BAKER 'DB' PACKER. ENGAGE STUB AND SET PACK—OFF OVER STUB AT 10567'. PUMP DOWN TUBING AT 500 PSI WITH NO RETURNS TO TEST P/O SEALS. DROP BALL AND PRESSURE UP TUBING TO 2,000 PSI TO SET PACKER. PRESSURE UP ON ANNULUS TO 2,500PSI. RELEASE FROM PKR. CBU AND POOH L/D 2-7/8" WORK STRING. DAILY:$18,136 CUM:$172,612 ETD:$172,612 EFC:$360,000 04/02/89 ( 0) RIH WITH "PX" PRONG MW: 8.8 NaCl TD:10850 POOH L/D 2-7/8" WORK STRING. CHANGE PIPE RAMS TO 3-1/2" AND PB:10798 TEST SAME TO 5000 PSI. R/U AND RUN COMPLETION ASSEMBLY. SUPV:DL LOCATE INTO PACKER AND SPACE OUT. LAND TUBING. R/U SLICK LINE AND SET PX PLUG IN 'X' NIPPLE AT 10546'. RIH WITH PRONG. (SSSV: NONE, BAKER 'DB' PKR @ 105001, BAKER 'FH' PKR @ 105941, 6 TT @ 10758'). DAILY:$143,640 CUM:$316,252 ETD:$316,252 EFC:$360,000 The above is Correct Signature Date Title 4111/ �89 Grilling . For form preparatio a d 'distribution see Procedures MaQ!uW Section 10, Drilling, Pages 86 and 87 Number all daily well history forms consecutively Page no. as they are prepared for each well. � AR3B-459-2-B ARCO Oil and Gas Company �i Daily Well History— Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. - Accounting cost center code District County or Parish State ARCO ALASKA INC. COOK INLET/KENAI AK Field Lease or Unit Well no. SWANSON RIVER ADL: A-028997 SCU 14-3 Auth. or W.O. no. Title AD6251 WORKOVER AUT• RA -11412-1 AlA—nn Operator Date A.R.Co. W.I. Producing Interval Total number of wells (active or inactive) on this Test time Production Oil on test Gas per day cost center prior to plugging and ARCO 48.4864 abandonment of this well Spudded or W.O. begun Date Choke size Hour Prior status if a W.O. ACCEPT GOR 03/26/89 Allowable 1600 Date and depth Complete record for each day reported as of 8:00 a.m. ROLL'N RIG 5 04/03/89 ( 10 RIG RELEASED MW: 8.8 NaCl TD:10850 R/D WIRELINE. TEST TUBING TO 3,000 PSI FOR 30 MIN—OK. TEST PB:10798 ANNULUS TO 2500 PSI FOR 30 MIN—OK. SET TEST PLUG. N/D BOP SUPV:DL AND N/U TREE. TEST PACK—OFF TO 5000 PSI AND TREE TO 8000 PSI. RELEASE RIG AT 1600 RR, 4/2/89.. DAILY:$14,134 CUM:$330,386 ETD:$330,386 EFC:$360,000 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity corrected Allowable Effective date The above is correct Signa re Date ,/L/�` Title ',7/ X Drilling Supp For form prepay i and distribution; see Procedures M nual, Section 10, Drilling, Pages and 87. Number all daily well history forme consecutively Page no. as they are prepared for each well. AR36-459-3-C Division of At1an11cRkMNlgCompany M ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL #296 TO: John F. Doyle FROM: Tom Wellman COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: Feb. 17, 1989 WELL NAME: SCU 14-3 Transmitted herewith are the following Blue Sepia Sepia Line olded Rolled Mlar Tape Collar and Chemical Cutter 1 1 Receipt Acknowledgement: Return reciept to ARCO ALASKA, Inc. ATTN: Judy Boegler ATO Post Office Box 100360 Anchorage, AK 995 10 - iv. •-...-a _ STATE OF ALASKA ALk-,XA OIL AND GAS CONSERVATION COMMI�,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend_ Operation shutdown _ Re-enter suspended well , Repair \ Plug ing Time Stimulate Alter casing , well _ extension _ _ Change approved program _ Pull tubing Variance _ Perforate — Other,. 2. Name of Operator 5. Type of Well:6. Datum elevation (DF or KB) ARCO Alaska Inc. Developments tioC Sttra9raphic_ R K B 1491 feet 3. Address 7Unit or Property name P. 0. Box 100360, Anchorage, AK 99510 0360 Service_ Sol dotna Creek Unit 4. Location of well at surface 8. Well number 14-3 650' FSL, 690' FWL, Sec.3, T7N, R9W, SM 9. Permit number At top of productive interval 650' FSL, 690' FWL, Sec.3, T7N, R9W, SM - 10. API number At effective depth 650'FSL, 690'FWL, Sec.3, T7N, R9W, SM 50 133-1010-00 11. Field/Pool At total depth 650' FSL, 690' FWL, Sec.3, T7N, R9W, SM Swanson River - Hemlock 12. Present well condition summary Total depth: measured 10 8 5 0 ' M D feet Plugs (measured) 107981 PBT D true vertical 1 0 8 5 0 'TVD feet Effective depth: measured 1 0 7 9 8' M D feet Junk (measured) None true vertical 1 0 7 9 8 'TVD feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 221' Yes 281MD 28'TVD Surface 2002' 11-3/4" 1350 s 2002'MD 20021TVD Intermediate Production 10850' 7" 700 s 1st Stage 108501MD 108501TVD Liner 1200 s 2nd Stage Perforation depth: measured 106201-106251$ 10629'-10635', 106381-106451$ 10674'-106841, 107081-10750' true vertical 10 61 8' -1 0623' , 106271-106331., 1 0636' -1 OVEC, 106721-10682', 10706'-10748' Tubing (size, grade, and measured depth) 2-7/8" @ 10649' OCT 211 1983 Packers and SSSV (type and measured depth) .r OR & G'as Cons. Baker FH pkr @ 105861, Otis Ball Valve @ 237' , 13. Attachments Description summary of proposal :4- Detailed operations program ._ BOP sketc 14. Estimated date for commencing operation 15. Status of well classification as: December 1 1988 16. If proposal was verbally approved Oil _'X_ Gas ._ Suspended _ Name of approver Date approved ` Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed A✓ /�.c/l.. 75. Title CZ DrillingEnaineer Date t 0/a 1 ge FOR COMMISSION LISE ONLY - Conditions of approval: Notify Commission so representative may witness J W B S A 4 0 0 5 Approval No. Plug integrity _ BOP Test _ Location clearance Mechanical Integrity Test _ Subsequent form required .�'e,proved Copy fIRK Ip`'t11. SIGNED BY Returned _;11`INIE C. SMITH 6. f CJ Approved by order of the Commissioner 'Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SCU 14-3 Gas Injector Swanson River 32" Tubing Change Out Procedure Prior To MIRU Workover Rig 1. Verify all dummys are in place and SSSV has been retrieved. 2. Set tubing plug in Otis nipple. 3. RU electric line and cut tubing with chemical cutter above top packer. 4. Circulate well down tubing taking returns from annulus to load well. 5. P.T. tubing and annulus to 2500 psi. Workover Rig 1. MIRU. ND tree. NU BOPE and test. 2. Spear tubing. Circulate and condition brine. 3. POOH with existing completion string. 4. RU and make junk basket/gauge ring run. RIH to top of tubing stub. POOH. 5. RIH w/retrievable bridge plug and set above tubing stub. Set storm choke. 6. ND stack and change out tubing head and 7" secondary seal unit. Make sure all pressure is bled off SC annulus. NU stack and retest. 7. Pull storm choke. Pressure test production casing. 8. PU packoff assy., nipple, space out tubing, and permanent packer with hydraulic setting tool. RIH. Swallow stub. Set packer. 9. POOH laying down. 10. PU 32" completion string with seal assembly. Stab into permanent packer, test packer, space out, land tubing. 11. Set BPV, ND stack. NU Tree. Test tree. Release rig. 12. Pull BPV. RU WL unit. Pull dummy and set circulation valve in GLM. Displace well with lease crude. Record SITP. 15. Release well to Production. REC SR/ 181 ih A 0 M ti WELL S -C-41. 14.3�... /s' e -A o r,er ASING N J I'VG 0ETA1(.. GL /3�.. L to Tubing, Nangea 1.0 , Ubing Hanger 1.0' ----- 237..2.1 47 A3. 2s" EUE 3rd Tbg. 220.21 , OT I3 RE:40VA3IE `AU VALVE 5,421 1756.31 l48 Jts. 27e" EXE 8rd Tbg, 151.0128 1 CAMCO .1-24 :•U►t DREOL 12.31 �► roo2 2964.371 1------- 3767.55' 1-4315,971 I ------ 4707.37 1 ------ 5066.O f T7056.73' D.e @ 7990' I ----10 , 541.68 38 its. 2'g" EUE 8rd Tbg. 1194.55' i CARO XX MANDREL -- 1 J, 586.31' 13.05 25 its. 2%w EUE 8rd Tbg, 790.13' CARO X•i MLIDREL OTyg "SN NIPPIZ, Position #3 12.971 17 its. 0/0" SUE 8rd Tbg. 535.45' CAMZO :moi MANDREL • :JE dr3 Tbg. 12.961 12 its. Asl EUE 8rd Tbg. 378..V, I CA:4CO .SAN ;REL fo. v- 63.x' t C U4CC0 : 34 XLti�REL 12.371 11 its. 21" EUE 8rd Tbg, 346.15' CANCO :Xi -WDREL D 10,650.E -- 1 CLkE0 NIPPLE 13.001 63 Jts. 210 SUE 8rd Tbg, 1977.24' CLMCO %Of XODr,EL 12.961 110 its. 2.8" EUE 8rd Tbg. 3,471.991 CRMO b0i WIDREL 13.00' 1 it. 2's" EUE 8rd Tbg. 319631 -- 1 J, 586.31' 10,592.991 BAKER "vH" PACb R 6.631 OTyg "SN NIPPIZ, Position #3 10611 • :JE dr3 Tbg. 31.x,6 fc, szs'.10 �b2b.Ob fo. v- 63.x' t C U4CC0 : 34 XLti�REL 13.00 � 10#649908, 1 PUP Jt. 2-g�' EUE Tbg. "D' 10,021 D 10,650.E -- 1 CLkE0 NIPPLE .321 a _ BRA �iN COLLET STINGER 3.�3 h-- •_ '�- ft .J o� � p+�o, .� � o o, X06 3 Jts, 2i6" O.D. Tbg. 97.36 " ,. ": Qj ° --got Iso' 10,750.64' BOTTOM CUT CN 45 1 v Top of Plug 4 10,7981 '1 T.O. 10,8501 1 34" GRAVEL FLCw PACKER LI11ER SEE LIM DETAIL DATED 1-19-72 A E w Avg. ✓.ww. i -so- �2 so 1. / 1 3L, " SURFACE CASING 2. 7" CASINO HEAD 13Vt " - 3600 PSI FLANGE ? 1*` - 3000 PSI XjYjr- 5000 PSI TUB I NO HEAD 4.'1 y(; - 5000 PSI X 1 I', - 5000 PSI CROSS-OVER SPOOL. 5. 11 " - 5000 PSI BLIND RAMS 6. 11`- 5000 PSI PIPE RAMS 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAININGAFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT' S 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 1. -FILL BOP STACK AND MANIFOLD WITH BRINE. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT I N WELLHEAD. RUN I N LOCK- DOWN SCREWS I N HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. S. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE P I PE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNINOJOINT AND PULL OUT OF HOLE CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND L I NES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI, 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY P'., 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. wu uA^A" A 1 Di17 ARCO Alaska, Inc. Post Office Box 100360 _CO Anchorage, Alaska 99510-0360 M Telephone 907 276 1215 COMM Cook Inlet/ New Ventures i Engineering r' ' August 19, 1987 EN Joseph A. Dygas , Branch Chief E N�`-�' United States Bureau of Land Management S T�1TC; Post Office Box 230071 FT U ECHI Anchorage, Alaska. 99523 �• Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wet Is in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories: 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker V Regional Engineer Cook Inlet/New Ventures HFB: JWR:ch:0006 Attachment AVG �ommissio� cc: C. V. Chatterton, Chairman S c.00. Alaska Oil & Gas Conservation Commission �horage Al Form approved. Budget Bureau No. 1004-0135 Form 3160-5 UNITED STATES SUBMIT IN TRaieLICATAe Expires August 31, 1985 LNovember 1983) (Other instructions on re- b. LEASE DR/[ONATtON AND SERIAL NO. (Formerly 9-331) DEPARTMENT OF THE INTERIORytroesift) BUREAU OF LAND MANAGEMENT A. IF INDIAN, ALLOTT/E ON TIME NAME SUNDRY NOTICES AND REPORTS ON WELLS (Do not qac this form [or pro CATION drill or to deepen or FOR YERDdIT " for such procposals.k to ) dlRerent reservoir. Use "APP '7 UNIT AGREEMENT NAME OIL L-1 (;AsJ] wct.t. ALN WELL X OTHER NAME Or OPERATOR ARCO Alaska I ADDIS// OF OPERATOR P. 0. Box 10 3 4. LOCATION Or %FELL (Report location clearly and n accordance with any State requirements.* See also space 17 below.) At surface Soldotna Creek Unit - 15 GTaancnn River_ Unit — 22 14. PERMIT NO. 'lls ELEVATIONS ( Show whether or. RT. OR. ate.) Soldo Creek/Swanson River Unit 1. FAaK ON LEASE NAME . FIELD AND FOOL, OE WILDCAT Swanson River Field . SEC.. T, R., U. OE ELK. A" EURYEs ON AMA . COONTT OR PAtit/H I 1L STATE 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Dalt NOTICE Or INTENTION TO: SUESEgvsN? RElOR'2 O!: TES? WATER SHUT -0r! PULL OR ALTER CASINGWATER SHUT -0r! REPAIRING WELL rRACTURE TREAT IIUL^_IPLE COMPLETE rRACTURE TREATMONT ALTERING CASING SHOOT OR ACIDIZ/ _ ABANDON* SHOOTING OR ACIDIZtNG ABANDOMMaxle REPAIR WELL CHANGE PLANS (Other) ( NOTE : Report results of mnitipl/ eompletion oR W411 (Other) Completion or Recompletlon Report and Log form.) 17. DSS( RiuF. I RorusED OR CONIPLE?ED OPERATIONS(Clearly state all perttoeut details, and give pertinent dates, lnciudlns estimated date of starting (Clearly proposed work. if well idirectionally drilled. Rive subsurface locations and measured and true vertical depths for all markers and stones peetl- nent to this work.) As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SRU 23-22 SCU12A-4 SCU 13-9 SRU -34-10 SRU 22-23WD SCU 13-4 SCU12A-10 SRU 14-15 SRU212-27 SCU323-4 SCU343-33 SRU 21-15 SRU314-27 SCU43A-4 SCU 14-34 SRU 31-15 SRU 23-27 SCU 24-5 SCU 14-3 SRU 432-15 34-15 SRU331-27 SRU 34-28�� SCU 33-5 SCU23B-3 SRU ,nui SCU341-8 SCU 34-4 SRU41A-15 SRU14A-33 L SCU21A-4 SRU43A-15 SRU 24-33 p,`jC� m1ss�on SRU 312-2 2 SRU 12-34 cots g om SRU 21-22 SRU 21-34 & Gas �ag�Di� ��hota9 18. i hereby cert attheforegoing i true and correct "�---� SIGNEI?" 44 TITLE v .,.t 0n l FngiiiRer DATA (This space for Federal or state office use) APPROVED BY TITLE DATA CONDITIONS OF APPROVAL, IF ANY: *See Instructions on Reverse Side Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the .. _ _- �____�._,__. —.._a ,._ ---tat:.,..e me to anv matter within its iurisdiction. Wells under Evaluation for Rate Potential 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 1 Wells being Wells SI Evaluated for for Inefficient P&A/Future Utility Production 212-10 12A-4 21-15 43A-4 31-15 24-33 34-15 12A-10 432-15 34-10 312-22 14-15 212-27 21-22 14A-33 21A-4 12-34 22-23WD 243-8 14-34 Wells SI unti 1 Blowdown 43A-15 314-27 331-27 343-33 o y fit r N �w ' N N, 7 Wells SI unti 1 Blowdown 43A-15 314-27 331-27 343-33 'I"1�1 TixC;I i40t,'i.1?I;:;I:(f�_^l'7' C1I I?i_(,I 3 i.'T nI ('I;I: (AI,A';KA) EPT . THE FOLLOWING IS A LIST OF MATER:IELL, ENCLOSED HEREIN. FD - Folded R - Rolled S - Sepia F - Film X -- Xerox B -- Blueline PLEASE CHECK AND ADVISE --IMMEDIATELY. COMPANY WELL HISTOU LOG 2" S'' 100 200 elt %.- � ! 11-5 ni(.w ,P t, I it BY RECEIVED BY REMARKS 0 i HE Fi :WE, TH1S StIETT &WNW w aw a P. O. BOX 7-839 ANCHORAGE ALASKA PRODUCING DEPARTMENT November 9, 1961 TELEPHONE DR. 7-6201 G. V. CHATTERTON DISTRICT SUPERINTENDENT RECENM NW 10 1967 Oil 8t Gas Scctj*()rj Division Of MinCs and Minerals Of IN-t--1-1 Mr. De D. Bruce Department of Natural Resources Mines & Minerals Division 329 Second Avenue Anchoragep Alaska Dear Sir: We call your attention to the attached first page of the Completion Report for well SCU 14-3. Please note the correction of typographical error in the Section., Town. ship and Range. Thank you. attachment Yours very truly., , /,u, C. V. CHATTERTON IM PRODUCING DEPARTMENT TELEPHONE OR. 7-6201 C. V. CHATTERTON DISTRICT SUPERINTENDENT jL P. • - •ANCHORAGE November �.. �ONgIDENT IAL Mr• D• D• Bruce Department of Natural Resources 321 Second Avenue Anchorage, Alaska Dear Sir r nalaw W 7 i"I Cil liDiyWGas �c rtic►r { on EBF Alaskt< Enclosed herewith for your information and files is the Completion Report on well$ SCU 14-3. Yours very trul-yj, CL C. V. CHATTERTON encl. Form P-7 SUBMIT IN DUPi.- ,ATE * STATE OF ALASKA ( See other In- structions on OIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE reverse side,, SD -133 - 1a/off WELL COMPLETION OR RECOMPLETION REPORT AND LOG * 6 LEASE DESIGNATION AND SERIAL NO. Ia. TYPE OF WELL:oil, F1WE ❑ 1\'F:LI, tTF,LL DRF LLJJ El Other 7. IF INDIAN, ALLOTTEE OR TRIBE NAME - b. TYPE OF COMPLETION: NEW, n'onic DEEP PrXG DIFF. 8. UNIT FARM OR LEASE NAME —WI nt'F.A rti niew nR.9V . Other _--_- _ —. .� 1, FARM NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. r,OC.ATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface At top prod. interval reported below At total depth 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. 13. DATE SPUDDED 14: DATE T.D. REACHED 115. DATE COMP SUSP O.R. ABAND. 116. ELEVATIONS (DF, RKB, RT, GR, -,TC)' 17. ELEV. CASINGHEAD 18. TOTAL DEPTH, MD & TVD 9. PLUG, BACK MD & TVDr. IF MULTIPLE COMPL., 21. INTERVALS DRILLED BY HOW MANY* ROTARY TOOLS CAHLE TOOLS 22, PRODUCING INTERVAL(S), OF THIS COMPLETION—TOP, BOTTOM, NAME (MD AND TVD)* 123. WAS DIRECTIONAL SURVEY MADE I 24. TYPE ELECTRIC AND OTHER LOGS RUN 25• CASING RECORD (Report all strings set in well) CASING SIZE WEIGHT, LB17T. I GRADE DEPTH SET (MD) HOLE SIZE CEATuNTING RECORD AMOUNT PULLED 7 / o f ,f`D /o. 6 2 I /900 26. LINED RECORD 27. TUBING RE--O—RD SIZE TOP (MD) BOTTOM (MD) SACKS CEAIENT* SCIIEEN (MD) SIZE DEPTH SET (MD) I PACKER SET (MD) 28. PERFORATIONS OPIEN TO PRODU . ON (Interval, size and number) 29. ACID, Si_CT, F ;ACI LIRE, CE:'JLNT SQJE7L2;, ETC. P /7,0 T DI:111TTT INTERVAL (MD) A:1IvU1tt' AND KIND OF MATE_UAL USED /oe_7ya /1068`51 >o 62-o -- lo6,-es- /0708 - /o7.fo E I r 30. PRODUCTION DA'Z'E FIRST PRODUCTION I PRODUCTION MEIHOD (Flowih , L* lift, purnping—size and type of pump) Ca ELI, aTATUS (Producing or :> tuL-in) DATE OF TEST. /LOURS TESTED ; CHOKE SIZE PROD'N FOR 011 —LILL. GAS—MCF. WATER --BEL, GAS -OIL I:.'.TIO TEST PERIOD FLOW, TUBING CASING PRESSURE CALCULATED OII.—$BL. GAS--TJICF. WATER—EBL, OIL GRAVITY -API (CORR,) PRESS. 24-HOUR RATE 31 • DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) ITEST WITNESSED BY 32, LIST OF ATTACHMENTS I hereby certify that the foregoing and attached information is complete and correct as determined from all available records SIGNELi _ G 9 _ TITLE _._ DATI. *(See Instructions and Spaces for 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 lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prcduction from, more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcducing 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 additional interval to be seperately produced, show- ing the ackJltional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL. GAS, 35. GEOLOGIC MARKE31S. WATER AND MUD 11 NAME MEAS. DEPTH RU 30. CORE DATA. Al'I'ACII BRIEF DESCRI J71ON4 Ott L.ITHOLOGY, POnOSLTY.. FRACTURES. APPAR> W DIPS tI ANM L:P,TEf."r'EV L, SIIOWS OF' OIGAS OR WATER. COMPLETION REPORT NEW WELL STANDARD OIL COMPANY OF CALF ORNIA - WESTERN OPERATIONS2 INC.•.OPERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND CF'FICE Anchorage Lease No. A-028997 PROP'r TY: Sold.otna Creek Unit WELL NO, SCU 14-3 SECT. `� N�� R. , Seward BW LOCATION: Surface: 6501 North and 6901 East from SW corner of Section 3. ELEVATION: 149r K.B. K. B. is 151 above ground DATE: October 31, 1961 BY: -- 04 -Vo CHATTERTON, District Supt. DRILLED BY: Rowan Drilling Company (Rig No, 33) DATE COMMENCED DRILLING: June 16, 1961 DATE COMPLETED DRILLING: August 2, 1961 DATE OF INITIAL PRODUCTION: August 6, 1961 PRODUCT ION : Daily Average 499 B/D Flowing Oil.......... 494 B,D Gravity......... 35.6 Water......,. 5 B/D TP .............. 1375 psi Gas,......... 107 MCF/D Bean............ 9/6411 SUMMARY TOTAL DEPTH: 10,8501 JUNK: None PLUGS. 10, 7981 w-10, 850 t CASING: 2211 conductor pipe cemented @ 281* 11-3/411 casing cemented @ 2002t w/1350 sacks cement. 7" casing cemented @ 100501 in 2 stages w/1900 sacks. 1st Stage around shoe with 700 sacks, 2nd Stage through DV collar @ ?9801 with 1200 sacks. I COMPLETION REPORT PACKER AND GAS LIFT INSTALLATION STANDARD OIL COMPANY OF CALIFORNIA. - WESlN N OPERATIONS,- - OPERATOR. I i AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage LEASE NOS. A-028997 PROPERTY: Soldotna Creek Unit WELL NO: SCU 14-3 Section 3 T. 7 N., R. 9 W., Seward B&M LOCATION: Surface: 6501 North and 690' East from Southwest corner of Section 3 ELEVATION: 1491 K.B. K.B. is 151 above ground DATE: June 20, 1963 :3 BY: CSV, CH TERTO, i rict Super'ntendent CONTRACTOR: Santa Fe Drilling Company, Rig #35 DATE COMMENCED REMEDIAL WORK: November 24, 1962 DATE COMPLETED REMEDIAL WORK: December 1, 1962 SUMMARY TOTAL DEPTH: 10,8501 PLUGS: 10,7981 .- 10,8501 CASING: 2211 Cemented at 281 11 3/411 cemented at 2002' 711 cemented at 1038501 RECEIVED JUN 25 1963 Petrdleuni 9rrp bivision of Mines Akisko Dept: of 1. �' Box 962 Soldotna, Alaska 99669 Area Code 913 Tel. 262-4496 Producing Formation Company Standard 011 Company _ ( ) Lease . SC L1 Well No. —3 Elevation (CHF, DF, K>3, etc.) 149# KB Field Swanson River- State Al a$ka ( ) Test Date Abri l , .1 975 - D't subsea or 10449 Zero Point KB GRD Depth Time a um , 10751 Static Test AD Tubing set at D P, psig .Casing -set at .10850 Production Packer at 3157 458 1 0620-10750 .229 Perforations 3548 391 2000 Subsurface Controls (Nipples, etc.) boo 3699 151 2000 Instrument Data 800 3904 205 Company Running Survey Ir - A. Wbite 1000 4152 Element -Range & No. K2 9280 ` 1020 Clock - Range & No. 3 • 200 .345 Calibration Date -1-75 76 200 .380 Static PressureData 4315 18 49 Pressure at Datum @ ) jl,2g psig 55 Shuit-in Time } •364 hrs. Press. @ Pi at Datum Tubing Casing Remarks Shut-in Tubing Pressure 2200 psig Press. Shut-in Casing Pressure psig Top of Oil Top of Water " Temperature at io600 feet 194 OF Date of Last Test Pressure @ Datum, Last Test psig Shut-in Time, Last Test �s fe Flow Test Data Choke. Size - in =Period of Stabilized Flow hrs Stabilized Production Oil bbls/day Gas MCF/day Water bbis/day .- Flowing Tubing Pressure psig Flowing Casing Pressure psig Remarks. th Operatox_. Sz•_ I�ic e�' Depth Time Press., AP Static Test AD Gradient D P, psig 0 2699 200 3157 458 2000 .229 400 3548 391 2000 .196 boo 3699 151 2000 .076 800 3904 205 2000 .103 1000 4152 248 2000 *124 1020 4221 69 200 .345 1040 4297 76 200 .380 1044 4315 18 49 .367 lo600 4370 55 151 •364 Time Press. @ A t Tubing Casing Remarks ft. hrs. Press. Press. 1, i � I 1_, I 1 i, 1� �. : , �, . I i I I I �11 I I - I I �, I . . I �, � I � I I I �:,� :� P," , - - � - - '- -- - I , -- -- - I _.,,_._ - 11 I ,� � � I 11 : I I I 11 I - - � . I . - I I - - 1.11 I., - � � I � '_.______._- _- .__-_____.._1 _.___ .11 � I I . � I . � I I . � :�, � � � - -_ - - -,-----" - I _ I . I I � : 1-1 I _' ' O' . . 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I + � I I I : . . . i I � I - - "I %.I- " �, . � I f f i I I I I i I I I I I " I I I il [ t I ) I i I I If I � , ) 4 " � � 4+ It I 1, 1, I - � t. -� I �, � I , H I I I I I � I i � �_ 41, 1 - I ! i i -11 i . I , � I I i % I 1 - �� t I I I I � 1 14� 1 � i E I � - I , , f I - I I , I I �, I , I I t! I I I t I f � t j � � I i I � I I I I I I I i I i I j � � . .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 1. � � - � . - I I I 1. I I . � .1 � . , I I 1, -N�* 6Aci CY-' x _Dz' I - � . I I : , , I I I I � v , -�:; i-i w -4 c v !,A , , I . I I ,. � � , �,� -, I � I I I . � �- A -1 I � 1 4 1 � " � . I . I I , 1, I I I . I � � I . * , I , " - � I I I � I - I , ;,' ,, . I �Ct '_' IIi.'24 nXj� 2,1 0 Z,�4 *� E�T;') �j . ' . - I I -1 -1 O 'ICAZI-41c - 'd IN : - � � , �. . I � - I . .� .1 , -1 , I , , � . il ,3pA,.1d Hdl'q,�.I�. N_ - , c;:!-dO:,E: . . � I-! � I ,�, . . . � � �11�1 I I 1. I I I I � . , 1 4 . . � I � I ; I . � I I . . 11 .1 , . I 1 4. I � � I �+ . . I . � I � I I , '. . I � I I , - �� I I I , I ." I I � I . � � ,1 , _L, " I I I � , I " �� I . I , I 1. � 1 . I I I ., 11 � I I I I I I I , 4 ! I I , I 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. � A COMPLETION REPORT - NEIN WELL STANDARD OIL COMMANY OF 'Al 1C)rjj1A WESTERN OPERATIONS, INC. -OPERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND a FICE Anchorage Lease No. A•-028997 PROPERTY Sold.otna Creek Unit WELL N'0. S CU 3.f �3 _ SEC . , T • .,.,. _2_ _ L1„ R. ,.,; _,L _...,.1 Seward FM LOCATION Surface: 650' North and 6901 Bast from SW corner of Section 3. ELC, V .TION: 1491 K.B. K. B. is 151 above ground D&TE: October 31, 1961 r CHATTERTON, District Supt. DRILIM BY: Rowan Drilling Company (Rig No. 33) DATE COMMENCED DRILLING: June 16, 1961 DATE COPTLE` EED DRILLINCAI: August 2, 1961 DATE 0f+ INITIAL PRODUCTION: August 6, 1961 PRODUCT ION : Daily Average 499 B/D 494 -3;D Flowing Gravity......... 35.6 OiI.......... 5 B/D TP 1375 psi Water........ Gas.......... 107 MCF/D .............. Bsan............ 9/64►t SUMMARY TOTAL Dr6PT. i : 10,8501 JttNK: None PL'+JGS r 10.4798'-100501 CASING: 22" conductor for tripe ceramted @ 28'. 11-3/4" casing cemented @ 20021 w/1.350 sacks cement. 7t1 casing cemented @ 10,8501 in 2 stages w/1900 sacks. lst Stage around shoe with 700 sacks, 2nd Stage through DV collar @ 79801 with 1200 sacs. COMPLETION REPORT Page 2 SOLD OTNA CREEK UNIT 14-3 Section 3 T.7 N. R. 9 W9,0 Seward B&M tandar Co. of Calif*,W.O.I. - Operator PERFORATICK RECCRRD: 4 - 1/2" holes/foot interval 10,6741-10,6841 4 - 1/2i1 holes/foot interval 10.97081-10,050f WELL SURVEYS: 1. Schlumberger Induction -Electrical Log, interval 20021 -?576, 2. it Sonic Log, interval 20021-7565= 3. t1 Induction-E�.ectrical Log, interval 75761--10..8521 44 1! Sonic Log, interval 75651-10,8141 5. 1, Microlog-Caliper, interval 10,1001-100521 21 6o, 11 Continuous Dipmeter, interval . (z00g,-86601 (90001-10,060, 7. „ Cement Bond Log, interval (1091201-1008501 4730-107501 8. 1, Gamma Ray -Neutron Log., interval 9500•-10, 7531 DRILL STEM TESTS: WSO - Test #1 on 5 - 1/2t1 holes @ 10,6181, OATSO) WSO - Test #2 on 5 - 1/211 holes @ 10, 7561. (WSO) COMPLETION REPORT SOMOTNA CREEK UNIT #14-3 Section 3 To 7 N. R. 9 W. Seward B&14 Standard Oil Co, of Calif., W.OvI. - Operator June 16, 1961 Spudded 0 4:00 Aft, June 16, 1961. Drilled 1611 hole 01 - 1290 t June 17,, 1961 +�irliruri rr irr� Drilled 1611 hole 12901 - 2030t 1290t drilled, 7401 drilled Reamed hole 0.20301 and conditioned hole for casing. June 18, 1961 rr,n rrrr rrrr rrrr i w �..�urr r Page 3 84 pcf mud 80 pcf mud Ran 11-3/40 casing. Cemented 11-3/41, casing at 20021 in a single stage around shoe with 1350 sacks of cement treated with 0.3% HR -4 using Halliburton power equipment& Used 1 top and 1 bottom rubber plug. Pumped 50 bbls of water ahead, mixed 1350 sacks of cement in 65 mins. using Halliburton truck, displaced in 14 mins. using rig pumps. Average slurry weight 116#. Bumped plug with 1400# psi. Full circulation throughout. Good returns. Cement in place at 6:30 AM, 6-18-61. Hookload weight of casing before cementing 140,000# after cementing before landing casing 122,000/# at time of landing casing 122,000# Casing Detai-1: 48 jts or 1984.711 11-X3/411 47# 8 RD, equipped with ■rr r Yrrr+� Baker shoe and Flexiflow float collar and 2 centralizers Top csg.to rotary table 17.421 Landed @ 2002.13 t June 19, 1961 war �rri rw �r r.rrr i Drilled mouse hole. Went in hole w/10 -5/8t1 bit and drilled cement 18401.. 20301., Installed BODE. Tested BOPE, kelly cock and casing w/1500 psi. Meld OK. Drilled 10-.5/811 hole 20301 - 3827t 7971 drilled. Stuck DP @ 31801 when coming out of hole. COMPLETION REPORT Page 4 SOTZOTNA CREEK UNIT #14-3 Section 3 T*,Z N, R, 9 W. Seward B&H tandard Oil Co.. of C if., W.Oolo.-Operator June 20, 1961 Worked stuck pipe. Spotted 100 bbls crude oil and 50 bbls Black Magice, Moved 1 bbl every 20 min, Circulated out oil to clean up.. Oil emulsion mud. June 21, 1961 Ran Schlumberger free point indicator and found drill pipe stuck on first drill collar. Backed off drill pipe at cross over sub. Left cross over sub and 9 drill collars and bit in hole. Went back in with 2 bumper subs mechanical jars and 9 - 7-.3/4t' OD drill collars. Conditioned hole and mud and screwed into fish, Bumped and jarred for 2 hours. Fish started moving,- Circulated and conditioned hole before pulling out, Added 50 bbls crude oi.l. June 22 1961 Pulled out fish. Went back in hole. Hole tight It 20301. Washed and reamed hole to bottom, Drilled 10-5/81, hole. 38271 - 4186, 359, drilled June 23 -June -261 1961 Drilled 10-.5/811 hole 4186t .. 63861 22001 drilled 71 pef oil emulsion mud 71-73 pcf mad June 27,E 1961 Changed over from oil emulsion to Gyp -Base mud. Drilled 1.0_5/811 hole, 63861 - 66271 2411 drilled 95 pcf mud June 28 - Jg .Z 2 1961 rrr■r■r r•n rr Drilled lO-5/8t1 hole 66271 - 7300t 673' drilled Drilled 8..1/211 hole 7300t «- 7420t 1201 drilled 98 pcf mud Page 5 SOLDOTNA CREEK UNIT 04-3 Section 3 T. 7 N. R. 9 W: Seward B&M Standard i Co. of Gal'lf,y W.O.I. - Operator July 33 196x Drilled 8-1/211 hole 74201 - 7575' 1551 drilled Ran Schlumberger Induction -Electrical Loa, 20021 to 7575a Ran Schlumberger Sonic Log, 20021 to 75751. Opened 8-1/20 hole to 10-5/811 ?3001 •- 74201 1201 opened 99.5 pef mud July 1961 Opened 8-1/20 hole to 10-5/811 7.201 75751 155' opened Drilled 10-5/811 hole 75751 - 76931 1181 drilled 100 pef mind. July 5 -July 23., 1961 Drilled 10.5/811 hole 76931 - 10,o7271 30341 drilled 96..99 pef mud July 24, 1961 Drilled 10«.5/811 hole 10,7271 - 10,8501 T.D. 1231 drilled 98.5 pef mud Circulated and conditioned mud to run logs* July 25, 1961 Attempted to run Induction Me ctrical Log. Tool would not operate. Attempted to run Sonic log, started hitting bridges ® 90001. Could not get below 1.0,1971, Went in hole and cleaned out bridges and conditioned hole. CO MET ION REPORT Page 6 SOLDOTNA, CRE UNIT #144'. Section 3, T, .7. Ni R0 W S21!ard, I�kM Standar o: of Calif* W406,14 r+Operator July, 25 ;4 & colt I,di 7 Ran induct onwF�le otr'idai t6g, interval, 7656i-10,8501* Ran Sonic log'j, interval 75651--10,8441, Ran Microlog"0aiiper, interval 10,100-.10, 850 t jik,. r 26, 1961 Conditioned hole. Attempted to run Dipmeter. FAt bridge ® 9554t Stuck tool @ 10,1001. Got loose and went to bottom.. Tool would not function properly. Pulled out of hole with tool hanging up. Left one upper arm and one pad off of tool. Wicked up bottom hole reamer. Got 3 stands below casing, tight hole. Pulled out and laid down reamer. Went back in with bit. Well started flowing over through DP. Well kicked heavily. Started circulating and conditioned mud @ 88001. Circulated water and gas out of hole. Jur� ly 2� : 1961 r+r�rr rnr rirrrrrMw Ran and washed to bottom. Bridges 0 9000-90301, 9120-91501, 9320-93501. 901 caved in on bottom. Junk is on bottom. Circulated and conditioned hole, Attempted to run Dipmeter. Tight ho3e @ 96001. Reached bottom and started logging @ 10,8501. Logged up to 10,1201. Stuck tool at 10,1201 and pulled loose. Tool did not function properly after pulling loose. Pulled out and repaired tool. Ran in and logged 10,0601 to 90001• Stuck tool at 90001, pulled loose. Rechecked sonde, functioning OK. Logged 86601 to 20021. Julz 28, 1961 Circulated and conditioned hole for 711 casing, Cemented 711 casing at 10,8501 in 2 stages with 1900 sacks of cement treated with 0.3% HR -4 using Halliburton power equipment. Used 1 top and. 1 bottom rubber plug. Zest Stage around shoe with 700 sacks of cement. Pumped 50 bbls of water ahead, mixed 700 sacks of cement in 20 mins. using Halliburton truck, displaced in 41 mins. using rig pumps. Average slurry weight 116#. 2nd Stade through DV at 7980t. Dropped DV bomb, opened DV 77 ports in 0 mins. Pumped 50 bbls. of water ahead, mixed 1200 sacks of cement in 35 mins. using Halliburton truck, displaced in 31 mine. using rig pumps. Average slurry weight 116#. Closed DV ports with 2500 psi. Full circulation. Cement in place at 12:15 AM, 7.2961. Casing free during lst Stage. Hookload weight of casing before cementing 210,000# after cementing before landing casing 236,000# at time of landing casing 236,000# W COMPLETION REPORT SOLDOTNA CREEK UNIT #14-3 Section 3,9 T. 7 N. R.9 TW#& Seward B&M Stan and Oil o. of Califop W*O.I. Operator Ju�1 289 1961 cont td. 7"_ Casing Detail Top 5 its 29# N-80 BT 207.471 Next 22 its 26# N -Y80 BT 935.891 11 87 its 23# N-80 BT 3696.52: 11 43 its 26# N-80 BT 1820.451 11 31 its 29# N-80 BT 2339.231 n 1 X over BT to L8R 6.781 tr 1 DV collar ® 7980x 2.001 t1 l X over 8 RD to BT 6.851 ,t 11 its 29# N-80 BT 479.281 tt 1 X over BT to 8 R 6.80t �t 50 its 29# P-110 L8R 2099.531 " 1 Pup P-llo -�i @ 14eS75� 05: Bottom 6 its 29# P`-110 L8R 260.981 (includes shoe & float collar) l0, 875.83' Above K.B. 25.831 Landed @ 10, 8501 i0z 29:0 1961 Page 7 Landed casing according to Standard Practice, Reinstalled BOPS and tested w/3000 psi. Held OK. Drilled out DV collar and tested w/3100 psi:. Held OICo picked up 2-7/811 tubing. 91 pef mud jjL3Z 30, 1961 OIYAYI�rAl1iY IY�IY YYY�/wYYYIrYY� Circulated hole. Ran 0em6nt Bond Log, interval 10753-47301 and Gamma Ray. -Neutron Log, interval 10753-95001. Shot 5 - 1/2" holes ® 10,6181 for WSO - Test #l. Halliburton WSO Test #1 'on 5 - 1/211 holes at, 10,6181. Tool Assembly: 2 outside BT recorders, 61 of pert 1d 2-7/811 tail pipe, type t1C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, h7d.re-, spring tester, 90t drill pipe and TC valve. Used 26531 water cushion. Ran on 10,5361 of 2-7/8" EUE tubing. Set packer at 105541 with 181 of tail to 105721.. No ISI press* Opened tool to surface at 8:10 PM for 60 min flow test. Light puff of air then dead for balance of test. Shut in tool at 9:10 PM for 45 min ESI pressure. Pulled packer loose at 9;55 PM. Recovered 51 net rise, drilling mud. COMPLETION REPORT Page 8 S OLDOTNA CREEK UNIT #14-3 Section 3-9 T#7 N. , R.9 jrT., , Seward B&M Standard i CrCo, of Cif., W. J.I.--aperator July, 30, cont 1d Pressure Data: Depth IH IF FF FSI FH (Final Pressures)of Gauge Top inside 951 6780 1247 1247 1569 6780 Bottom inside 9521 clock stopped Top outside 12521 6885 1255 1255 1600 6885 Bottom outside 12531 6872 1238 1238 1574 6872 Charts indicated tool opened OK. WS July --31s 1961 Drilled out baffel plate and cement to 107981. Conditioned hole. Perforated 5 - 1/211 holes @ 107561 for WSO Test #2:, Halliburton WSO Test #2 on 5 - 1/211 holes at, 10,7561. Tool Assembly: 2 outside BT recorders, 6 feet of perf 1d tail pipe, 7T1 type C hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders,hydro- spring tester, 901 DP and TO valve. Used 27471 of W.C. Ran on 10,6931 of 2!7/8" EUE tubing. Set packer at 10, 7091 with 181 of tail to 10,0 7271 • No ISI. Opened tool to surface at 9:45 PM for ?5 min flow test. Puff and light decreasing blow for 10 min then dead. Faint blow started again after 15 min and continued for 35 min. Dead for balance of test. Shut in tooi at 11:00 P14 for 50 min FSI pressure. Pulled packer loose at 11:50 PM, Recovered 1301 net rise; 11 oil, 1291 slightly gassy oily drilling mud. Pressure Data (Final Pressures) Iii IF FF FSI FH Depth of Gauge Top inside 951 6857 1258 1303 1922 6857 Bottom inside 952 b840 1212 1270 1071 684o Top outside 1252 6942 1260 131.5 1931 6942 Bottom outside 1253 6869 1226 1290 1887 6869 Charts indicate slight plug after 15 min and then open for balance of test. Top Recovery - slightly, gassy, oily., clabbered drlg. mud Test filtrate 0.80 ohms/m @ 700 w 440 g/g salinity titration method = 384 d9 chlorinity COMPLETION REPORT SOLDOTNA CREEK UNIT #14-3 Section 3 T. 7 N,,q R.9 W. Seward B&M Standard Oil Co, of Calif.., W.O.Io-Operator July 31, cont Id* WSO Test #2 continued: Sample top of tool - gassy, oily, clabbered drlg. mud. 0.68 ohm/m @ 700 = 510 g/g salinity titration method as 451 g/g chlorinity Recovery is rat hole expansion plus very small entry. WSO Page 9 Au&us t 1, 1961 Ran and .landed 2-7/811 tubing @ 10658t w/marker joint @ 105231. Removed BOPE and installed Xmas tree. Tested w/5000# water, held ok. Ran collar locator log and capsule jet string, August 2,, 1963 Perforated 4 - 1/211 holes/foot over interval 106741_106841 and 10708-10750'. Flow tested well. Installed Xmas tree and tested with 3500 psi for 15 mins. Held OK. Commenced displacing mud with oil. Pumped 50 bbls. of water ahead, followed by oil. Formation oil to surface at 3:00 AM. Started flowing to trap at 5:001M. Representative flow rate and cuts as follows: FLOW RATES BEAN TBG. CSG, TRAP FLOW PERIOD OIL GAS SIZE PRESS. PRESS, PRESS. 1 hr 1104 B/D 236 MCF/D 16/64" 950# 704# 55# 1 hr 432 B/D 87 MCF/D 8/6411 1440# 1190# 55# % TOTAL CUT % WATER % EMULSION % WID AND MUD CORR. GRAVITY 0.6 0.2 0.2 0.2 36.1 0 0.4 0,2 0.2 0 36.40 COMPLETION REPORT Page 10 S OLDOTNA CREED£ UNIT x#14-3 Section 3 T. 7 1i. i_R. 9 W. 2 Seward LLCM Stann and 0 l oC , of Calif. .V W.0� .I. - Operator August 21 cont td. Shut well in at 7:30 AM. Shut in pressures; tbg. press. 1660 psi.. csg. press. 1.00 psi. Produced estimated 230 bbls. formation oil, Flowed 230 bbls. to tank. Installed coaasco plug.: Rig released 8:00 AM} August 21 1961 COMPLETION REPORT SOLDOTNA CREEK UNIT #14-3 Section 3 T. 7!I" -R. 9 Wo, Seward B__&M Standard Oi Go. of Calif:, W!-* : Operator DEVIATION DATA: e`er, Degrees t�t53 s 0 0 4o6ot 1045t 43201 1000t 51401 1000,. 5690, 10451 60701 10451 64701 no picture 6600, 10301 6878, 10301 71601 10451 7600 t 0045t 78401 10301 8180t no pasture 83151 10451 8567' no picture 86611 10451 90961 10301 93901 10i5t 96461 20001. 99361 no picture 100291 2000t Page 11 rorm P-3 Submlt "Intentions" in Triplicate REV. 8-30- h "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propu_ials to drill or to deepen or plug, back to a diffierent reservoir. Use "APPLICA'T'ION FOR PERMIT—" for such proposals.) 1. WELL WELL a LL OTA ER 2. NAME OF OPERATOR Standard Oil Company of California, W.O.I. 3. ADDRESS OF OPERATOR P. O. Box 7-8391, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 650' N and 690' E of the SW corner of Section 31 T7N, R9W, SB&M. OIR _T C. GEOL C. ENG I!' S. API NUMERICAL CODE ' I Lwv 2 ENG - 8. LEASE DESIUNA'110N AUND SERI 10. 3 EN i 4 ft.G A-028997 S ENG 7. IF INDIAN, AI.LOT'ME UR TRI13i NAT GEOL 2 GEOL 8. UNIT, FARM OR LEASE NAME 13 GEOL Soldotna Cre k REV 9. WELL NO. DRAFT S C U 14-3 SEC" 10. FIELD AND POOL, Olt WILDCA CONFER: Hemlock Zon FILE:l� 11. SEC., T., R., M., (BOTTOM HO OBJECTIVE) , Section 3 T7N, R9W, SB&M 13. E,LEVATIC"I's (Sliew whether DF, RT, GR, etc. ,aL. rc.ruvua aw. 149' KB 1t 14. Check Appropriate Box To Indicate Nature oT Notice, Report, or Other Data NOTICE OF INTENTION TO: NUBSEQIIENT REPORT Or: _ TEST WATER SHUT-OFF POLL OR ALTER CASINO WATER SHAT -OTT RZPAIRiNO WELL 1 ) 1111 r >rRACTCRE TREAT MULTIPLE COMPLETE �_� TRACTVRZ TRZATMZNT ALTERING CASING SHOOT OR ACIDIZE X ABANDON* _) SHOOTING OR ACIDIZINO U ABANDONMENT* REPAIR WELL CHANGE PLAITS (Other) (Other) j (NOTE : Report results of multiple completion on Well Completion or Recompletion Report ar.d Log form.) r IS. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates. Including estimated date of starting any proposed work. This is a supplement to the Notice dated 6-29-71. 1. Kill well with heavy mud. 2. Install and test 5000# ROPE. .- 3. Pull tubing and production equipment. 4.` Perforate with 2 jet holes per foot at intervals 10,620'-101645'. S. Run tubing and recomplete well. OF r%- Dr °.� C, ;r -1971: DIVISION OF OIL AND GAS ANCHORAGIS 14. I hereby ce Ufyctb9 t fo>•Wp ng Ifte "d correct Dist. Superintendent 7-/ SIGNED TITLE DATE (This space for Stat Mee us Y APPROVED BY TITLE :i/ LrO/us» e r DATE CONDITIONS OF APPROVAL, IF ANY: - gpproved Copy See Instructions On Reverse Side Ret Form P-3 t' crn , r, r,r" A! ACV A Submit "Intentions" in Triplicate & "Subsequent Rcports" in Duplicate 1¢. Check Appropriate Box To Indi-cate Nature Nbtke, Report, or Othor Uata NO.f`ICra, Or INTENTION TO: SUBSEQUENT REPORT Or: TEST WATER GHUT-OSI!' ` PULL OR ALTER CASING WATER SI OT -OSA' REPAIRING WELL FRACTCILE TREAT I MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASINO SHOOT OR ACIDIZE ABANDON$ SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) (NOTE: Report results of multiple completion on Well (other) Install gravel pack, l i ne rx] Completion or Recompietion Report and Log forin.) 15. DFSCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Attached is a program to install a combination inner liner in SCU 14-3 and to gravel flow pack the liner. Purpose of work.is to test gravel packing as means of eliminating sand production. _ I PE.:J-,vl� i j � �? DIVISION OF OIL AND GAS ANCHOotAott 16. 1: hereby certify tha - ebe/fore:c ,i = x r fit r re -- lit-'W — , 6-- ' ' 71 1 cxr JD _� TITLE � � uneri_ntglad.ent nA1�.________ l __-- (This space For State office ). ri � - API"RE}6'L'I? 11i' - TITLE - / �"`/ll.�lC-i�,'.-� CONDITIONS OF &Pr -RC VAL, IF AN- : Approved Copy Sea lnstrucfl hs On Reverse Side Returned -)9-71' dI RR." CODE OIL AND .G/�S CONSERV��TICUN COMMITTEE F5.AI"INU E" DESIGNATION ANI') SERIAL NO. SUNDRY NOTICES A14D REPORTS (Do not use this form for proposals to drill or to deepen: or plug back to a diffierent reservoir. A— 'S 2 S 9 9 7 Use -APPLICATION FOR, E'I�RNiIT--" for such proposals.) V 7. IF INDIAN, ALLOTI E7: OI2 '1'II I.LiE IV ASJ1I: OILOAS (� VVELL L&-' w.FLL _J OTHER 2. NAAIL OF OPERATOR. a. UNIT, FARM Olt LIGASE NAME S'.tandard Oil Company of California, W.O.I. Soldotna Creek 3. ADDRESS OF[)PERAT OR 9. WELL NO. P. C. Box 7-539, anchorage, Alaska 99510 SCU 14-3 4. LOCATION OFWELL >�® 10. FIELD AND POOL, OR WILDCAT At surface Swanson Riyer 650' North and 690° East from SW 11. SEC., T., R., M., (L0170M 11OLE, OBJECTIVE) corner of Sec. 3, T7140 R9Wr SB&M. Section 3 T7N, R9Wj SB&M 13. ELEVATIONS (Show whether DF, RT, GH, etc_ 12. PERMIT NO. YB 149 , 23-63. 1¢. Check Appropriate Box To Indi-cate Nature Nbtke, Report, or Othor Uata NO.f`ICra, Or INTENTION TO: SUBSEQUENT REPORT Or: TEST WATER GHUT-OSI!' ` PULL OR ALTER CASING WATER SI OT -OSA' REPAIRING WELL FRACTCILE TREAT I MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASINO SHOOT OR ACIDIZE ABANDON$ SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) (NOTE: Report results of multiple completion on Well (other) Install gravel pack, l i ne rx] Completion or Recompietion Report and Log forin.) 15. DFSCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Attached is a program to install a combination inner liner in SCU 14-3 and to gravel flow pack the liner. Purpose of work.is to test gravel packing as means of eliminating sand production. _ I PE.:J-,vl� i j � �? DIVISION OF OIL AND GAS ANCHOotAott 16. 1: hereby certify tha - ebe/fore:c ,i = x r fit r re -- lit-'W — , 6-- ' ' 71 1 cxr JD _� TITLE � � uneri_ntglad.ent nA1�.________ l __-- (This space For State office ). ri � - API"RE}6'L'I? 11i' - TITLE - / �"`/ll.�lC-i�,'.-� CONDITIONS OF &Pr -RC VAL, IF AN- : Approved Copy Sea lnstrucfl hs On Reverse Side Returned -)9-71' SOLDO'LNA UNIT 1-4-3 Junes 81 1971 ?I; S!;"]T COIN'DT" TONS Tottz1_ Depth : 101050, Ping a 10,7901-10,8501 Cass ng 22E1 conductor pipe ccrlen ted at 28' 11. 3lz4 °° all 4711 8rd cent ented at 2 , 002' .7" 23R, 26:` and 29'� cemented at 10,8501 711 Casing Dot:.ail: Bottom 2,375' (1.0,850'-8,475') 294 P-1.1.0 LS w/14.05' pup at 10,575' 7` (8;475'--s14G-S' ) 1 r-aver Butt to 8rd 473' (814681-7f9691 29 N-80 Butt 78 (7,969T-7,08)21) I X-over 8rd to BT 2' (7,952`-7,950') D.V. Collar 7(7,9P,0t 7,973' } l x--over BT to L8P 1,339F (7,9731•-6,634` } 29- 11-80 BT 3.,820' (6,634'-4,814' j 26'17 1-- 80 BT 3r6971 (4,814`--111.171) 23i= N--80 BT 93ti' (1..1171- 1611) 2O'S jr' .I-80 BT Top 181'_ (1811- 01) 29 nV, 11-80 BT Perforations: 5-1/2'1 jet holes at 10,6181 and 10,756' for 11SO's 4-1/211 holes/foot 10,674'-101684' and 1017081-101750' ` 'Lxbinq Sec attached 11 Gas Lift �'.:bing; Design" du ted 12--1--62. Tubing is all 2 7/G" Packer at 10,605' . V?c Jun!_ air I C0r,dit:j.a,i of Ca I'nq • No junk or bad pipe rcport:cu. -- DIVISION OF OIL ,�.itiD GAS Datum 1.5' above concrete mat. at ::.L'. elevation of 1,1131 ANCHORAGFI 13131'!': _C ClT'r1 !`V ':l"'T'—f ;? , . C: L'1 x C:lf. P? Otit'.C%l U21 1:; .1583/33 r_./n (o/w) and i:C :;G1:��0)•1 j�2'C_-sul:e is �I1)�)ro-zim"t;Cl y 4%►00 }% bi ;'.c� .;:l11t: i rl t' i:1SJn j?7'C!:�:t::::C`. ]-:' apprc) xJ.1;iato1y 3!)no p. ig Class 111 5000,, DOT'J's will be utilized. t 4 7. cra.rcl flovi park combination flush 'joint :3 1/2" liner. utilizing BroN!n oil 'lcso)_ ;crvices. Dott.clm of line1- is to 1)C. at ).C'►,7�G' � , iilit� i �11: ;"�:iC;�er at'. 1.0, C30' +. 5 ).C%i:1 (1, port Ion Of a..1.I'tC'.r .is to )-)C 0. 0 moo" ni:t?(Je vire wr-appc� 1. P—ac '. ))(-h_;.An liner %•'_1121 8 12 r1c`u21e I1 1)?''. :':�l'.3 C iIIC: CZ�, s 1.I1C1 i. c:z.tf.':� (� ): iIVC:1. l:i to the t1)C I)VIII up andreverne Out any gravel. lel:t: in the t1l"i �. nrn 3 joisti.l�rci- With SOill`__: to prick Off i)ot:t: c:ol'.itr a:�ct with collet ni*rcr to lett -11 �,I1d scal ill tot) of Wolvori.ne f pacl:t:rotYc:r to 2 7/1", zlbovc: 1);;ckcr. N1111 ? �. 7/�s" t:11brlc1 aria ctr: ). i 1.�r,11rt1.r :1 t « l:7:isr:c:e. D01i.ttll t(7) ).)n i'l':"r►ti::2ivri to Whilt! I-111117ing 5.11. 111:;Lal l Ot,ir: t tl}4J 11�r_' i o t:v i��,3t,tt: i, t. t:.�0t. . r,i11.01 ill t: t:np of Wo.)vc ne. 1'rtr..l;.r>�• at, a.tl,t�:li�` , pickuta calci :c>>.eCe e, tit. Latch into top of E arc 14 1:,rDAT, z>IMCr,rlr5 3,. t � Install C.c)sasco back pr. cssur e valve. t -love 3.Iz contract rig. Kill well with 71--73 pc•f inverted emulsion mud. Thi:; provides a hydro- .g static Vr.essure of 512-60-x54.10 ]isi5 at top of perforations at 10, 07,1' . - - 140te: P):ior to mixing- laud, thoroughly c1C'c'1I1 nud tanks, Zinc_; c'IIId stitch to insure that clean nud will be available for gravel packing �= • operations. 2. Remove tree and il:sta.ii Class IIF HOPE consistinU of 10" Shaffer. =t I,WS a cri es au?�1.e Gate- and Ilydril GK series x.500 proven ter. Remove Cosa: (:o F3P valve and install Cosasco plug. Test chole line:;, kill line, blind rams, pipe rams and Hydril to 5000 prig for a rti.nir. u.ni T of 15 minutes. c 3. Y Remove Cosa:sco plug and unseat donut. Rotate tubing to release - - Brown Hs• -10--1 packer at 10, 605 ` . Pull tubing and packers. Note t. Pave a "CC"- retrieving tool on -hand in case the "CC" joint at f 10,594' releases. - 4. flake an open end clears --out run, •with sam toot:i collar, to ton of plug at 10,798' . Run: ioDen—ended with tandcmt 7" casing scrapers., _ Scrape perforations and circulate hole clean. ss S. Run Hro�?n 0 l Tool. push out washer with 1' cub spacing and wash all perforations to insure that they are open.. Do not exceed 5000 Iasi surface pressure. 6. Run t1lbi.ng with ce-menting type pac'cer and set at 10,040±. Pressure test e.nnulus to 2500 psi. 37olcl 1500 psi on annulus during ren,aix-4J ng put.Epi:,ng operat iol:s. Establish an injection pressure for 2 1/2 BPI•! :ate (c)r at lot"rcr rate i- near 5000 psi surface pressure limit) . F. Pa -}k for_: _-t —Lon wi.LZ 3 - 12 ncsu / (0.09' O.O 1G'") c -avol, pumping at 1/1 :P,i (or at,3Gi�c� �. r.?1tti (<1J �i.i.i :Ie lCat.e.. �� hon .injection pressure Y j[1) incrC.t._'ses 50o psi a'Dovc tl-,ct. i7��;t,.G3.7� ��•l1(-�u" nressur.C, discontinue punPi.l:cj Do not cxccca 5000 nsi st,::iacc prestiUI..o. P.cc.olilnended 9rave1 - conccllirati.oli is olle--haall. (1/2) pound per gallon. 7. cra.rcl flovi park combination flush 'joint :3 1/2" liner. utilizing BroN!n oil 'lcso)_ ;crvices. Dott.clm of line1- is to 1)C. at ).C'►,7�G' � , iilit� i �11: ;"�:iC;�er at'. 1.0, C30' +. 5 ).C%i:1 (1, port Ion Of a..1.I'tC'.r .is to )-)C 0. 0 moo" ni:t?(Je vire wr-appc� 1. P—ac '. ))(-h_;.An liner %•'_1121 8 12 r1c`u21e I1 1)?''. :':�l'.3 C iIIC: CZ�, s 1.I1C1 i. c:z.tf.':� (� ): iIVC:1. l:i to the t1)C I)VIII up andreverne Out any gravel. lel:t: in the t1l"i �. nrn 3 joisti.l�rci- With SOill`__: to prick Off i)ot:t: c:ol'.itr a:�ct with collet ni*rcr to lett -11 �,I1d scal ill tot) of Wolvori.ne f pacl:t:rotYc:r to 2 7/1", zlbovc: 1);;ckcr. N1111 ? �. 7/�s" t:11brlc1 aria ctr: ). i 1.�r,11rt1.r :1 t « l:7:isr:c:e. D01i.ttll t(7) ).)n i'l':"r►ti::2ivri to Whilt! I-111117ing 5.11. 111:;Lal l Ot,ir: t tl}4J 11�r_' i o t:v i��,3t,tt: i, t. t:.�0t. . r,i11.01 ill t: t:np of Wo.)vc ne. 1'rtr..l;.r>�• at, a.tl,t�:li�` , pickuta calci :c>>.eCe e, tit. Latch into top of v h '•k 0 sC;tj 1 3 REr;l-r)YAi, PrR6CI'AM . 9. Install Cos:scO plug. Remove 011OPE, Inr,t:a11 'X-mas tree; test tree to 5000 psig with Glean ,rater. Note: Tree to have double master valves. 1.0 remove Goscksco plug- and displace mud with crude oil., as directed by Production Fore::1an, 1.1.® Install Cosasco BP valve and release rig. 3-2, Remove Cosa --co DY"valve and produce from lover zone at 2--300 B/D. Gradually it-cr-c ase rate over a period of several days until 1000 D/D rate is reached. Coordinate rate incr.cases � L- eng-Iieer_a. I Ta.l:e frequent gauges and inspect rauge trap for sand deva��itioii asccordi,ng to schedule requested by engineering. sample any sand which night deposit in gauge trap. Yti014DZELL . �/5 C. t;, VIJ.Ison-W R. Tinker tel,econ rte, COMPLETION REPORT - PACK-!,?. AND GAS LIFT INSTALLATION Page 2 SOLDOTNA CREEK UNIT SCU 14-3 Section 3 T. 7 N, R 9 W. Seward &&M STANDARD OIL COMPANY OF CALIFCRN.I.A, t°dESTERN OPERATIONS, INC - OPERATOR November �4, 1962 Commenced rigging up at 1:00 AM, November 2527, 1962 Winterized rig. November 2 8, 1962 Conditioned Black Magic Mud and killed well. Removed x-mas tree and installed BOPE.. November 29, 1962 Pulled tubing loose, ran to bottom and circulated before pulling out of hole. November 30, 1962 Ran 7" casing scraper. Reran tubing equipped with mandrels and one packer. All tubing is 2 7/8", 6..5# N-80 8R R2, TUBING DETAIL K.B.Depth K.B. to landing flange 16,00' Donut and pup joint 2.50' 18.50 45 joints 2 7/8" tubing 1422..79' 1441,29 Cameo MM Mandrel (#1) 12.95' 1454,24 46 joints 2 7/8" tubing 1452.40' 2906.64 Cqmco MM Mandrel (#2) 13,00' 2919.64 41 joints 2 7/8" tubing 1294.53' 4214,17 Cameo MM Mandrel (#3) 13.00' 4227,17 33 joints 2 7/8" tubing 1037.71' 5264.88 Cameo MM Mandrel (#4) 13.02' 5277,90 30 joints 2 7/8" tubing 945-51' 6223.41 Cameo MM Mandrel (#5) 13.00' 6236,41 26 joints 2 7/8" tubing 820,74' 7057.15 Carrico MM Mandrel (#6) 12,91' 7070.06 22 joints 2 7/8" tubing 692,37' 7762.43 Cameo MM Mandrel (#7) 12.90' 7775.33 88 joints 2 7/8" tubing 2778.91 10,554.24 Cameo Sleeve valve 2.64' 10,556,88 1 joint 2 7/8" tubing 31,65' 10,588,53 Brown CC Safety joint 1,08' 10,589.61 Pup joint 10, 06' 10, 599.67 04 COMPLETION REPORT - PACKER AMID GAS LIFT INSTALLATION Page 3 SOLDOTNA CREEK UNT SCU 14-3 Section 3 T. 7 N. R. 9 W. Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR TUBING DETAIL (cont Id) Brown 2 7/811 X 7" HS --16-1 packer 2 joints 2 7/8" tubing Camco "D" Nipple 2 joints 2 7/8" tubing Venturi Shoe Tubing Landed at December 12-1904 5.98' 101605.65 63.34, 10,668.99 .921 10,669.91 63.35' 10,733.26 .44 10,733-70 10,733.70' Removed BOPE and installaed x-mas tree. Displaced mud with oil, and set packer at 10,6001. Returned well to production. Rig released at 6:00 PM. aat "72vib 3 S.R. HANSEN 1 J 11iff 1.11 NGC: Blldy-114 Appruval expires 12-31-W. UNITED STATES LAND CV Anchorage. DEPARTMENT OF THE INTERIOR LEASE N!! 'I?r".f? A-028997 GEOLOGICAL SURVEY SOldotna Creek LESSEE'S MONTHLY REPORT OF OPERATIONS ;tit.- Alaska G{outat y _Kenai _ Peninsula_-._ -,-I t ---..._Swanson River �. The. follou.7i71. Is a oorrect report of op,,rat(oiL.0 prG(fitelion. (includlirtY (trilliltf, and r'vells) for th-e rnonl h, uj" .------UIS tbor -- :(.62 . $oldotna Creek Unit P• 09 Box 7--839 (1 _)u n i� STAD$jA i _GAIL Q)# ,OF CAi,IF'..W.O.I o Anchor age Alaska ,e HAt C. V. �ERTviV BRoadwa _ -6201 .l ; r �t.t's Gi.tt District Superintendent SFC. AND r y\ F i L I1A73 I { --'— —� ". FT, OY OAS 1 R + t, Twp. RANGE ` BABL'E19 OF lits. ORAFI?Y ( � ASO LINL WATEP (i( (11 .iril, n lr.wn. r•, r,v..; j4 UB ji i iu U. Pn o(iccwu I - t (Ill tt1011Sflllrl4� i IZ. I , r'r)�'1:B}+.0 tlr:ltt', SO 8f t1.<�- 3 7N 9W SOLDOTNA CREEK UNIT 14-3 (23) R�MEUTAL W K a SW iii M Ran aasi scraper. Ran and landed 2 7/8+ tubing at SW i ! i i 10731 '. Removed BOPS and installed x-mas' tree. Dis- placed *d with oil. Set packeriat 10800'o Returned wll to production* I i Rig cele sed Diecember 10.1962 i act I i U.S.G.S. i- Mo Ho Soyster State - 'o R. Marshall .S14 - C. WQ Perry R. R. Ritter j - 1r oduc is ng i 1 RFCrIVED' JAN I 11963 f'e,roleu ri. Ii1 Branch Dept.of M"105 and Minerals L3 ept• Of .__.. Naturud RQSQUM� NOTE.--'T'here were ---------- __..---------------------------- runs or sales of oil; ----__ ___- ._ ___ M cu, ft. of gas sold; --------------------------------------------- runs or sales of gasoline during the month. (Write "no" v. -here a.l;,)licable.) NorE.—Report on t -his form is required for each calendar month, regarclle s of the .tatus of operations, and mint be filed in duplicate with the supervisor by the 6th of the suceeeding month, (unless otherwise dinteted by the supervisor. Form 9-329 (January 19m) 16-25766 -d U. S. GQV%RRMSti ^R1NrI46 urFn:a UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Butlgut F3iu-atl \'U. 42 Fi 3iG.:r. Approval expires 1' - 31-rlU. 'LAND OFF, L -_-Anchorage i-.eASE Nur,,i-Fi4. .A-428997 UNIT Soldotna. _ Creek Unit f LESSEE'S MONTHLY REPORT OF OPERATIONS 4 State ---..--_Alaska------- county Kenai_Peninsu].8 -- Field Swanson River The following is a correct report of operations a.-nd production (inf.luding 7rilline and produc,in wells) for the irwnth of ------------November. ------- -_, 19-621 - Soldotna Creek Unit .1ent's address --- __Fo Qs__P-9X_-7-839--_ _-. --- __-.-.- _ coin a,2, STAND OIL CO. OF CALIF. W.O,I. ---------- ------ --- -- Anchoraggs_ Ala3ka -- Ne,t�>d - - R ••6201 District i'i eRiORendent Phone ------------ --- ---- ------------------------------------------- .9yerLt s ttti� -._. Superintendent GALLON9 Of?==BARItuLs OF REMARKS BEC. AND I WEIL I Dais C(T. FT. OF 0 A I � I i (II drilling, depth if shut town muse; rrWP. RANGE jII I BARRELS OF 011. GRAVITY Gtsol.l. E rvATRtt (11 OF + NO, t Pnoane— (In thou aild5) I r darn :.nd rr�Itit of ti:,! I r q: n, luiy !I 1tIFIF c RI»c.oc.� us:'D nout,�, so Mute) cununt u! � s) �__-_U—---- - 7N 19W s SOV 14-3 K 23 ) Remedial, ork Black Mag c Mu Pulled tu�inga ormnenced l ovember $5, 1962 Killed well with Removed x-mas ttee and nstalled BOP& Running basing setapero t I j v I f 1 . U.S.G.S. M, Soyster State - T� Ro Marshall Richfield - C o I lde Perry E RO I Ro Ritter Files - NoTn.—There were --------. ------------------- ------ runs or sales of oil, --------------- _-_- _---.-_--- M cu. ft. of gas sold; --------------------------------------------- runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.—Report ou this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form. 9-329 16-25766--8 U. GOYCNNMLNT -RWING OFIFIC[ (January 1950) UNITED STATES DEPARTMENT OF THE. INTERIOR GEOLOGICAL SURVEY Budget Burow No. 42-1056.5. Approval expires 12-31-60. nch LAND OFFICE ----Aorage ------------ LEASE __--_LEASE NumBEP __A!rUj +^.7_�" 7______________ UNIT -- -�4�41a--- k -- ------ LESSEE'S MONTHLY REPORT OF OPERATIONS Alaska Kenai Peninsula ---------------------------------- County --------------- ----------- ---- -- Field ----Swanson__River------------------------------------ StateThe following .is a correct report of operations and proditetion (including drilling and producing wells) for the month of ------------------ Augugt .----- - -, 19.61, ---� dig-'$ 'Unit -------------- -------------------- ------------------ .ggent's address ----- -p• 0' Standard Oil Co. of Calif. --Box 7-�39 -- -- --- -- ----- - ---- Company --mss8e4ns �l�G•-------- Ane-hora�e, Alasxa-- - - -- Signed 0_V,_-------------------------------------- ==-------=------------ ----- --- Phone ----------------------J3 R9QL_d_V-zY--?_-6201------------------------------ J(Yent's title Distriet__SuperintendOnt------- $EC. AND TWP. I RANGE OF X 3 7N 9W i I SWC Si�4 i I i � I � Qct I GALLONS OF BARRELS OF I REMARKS ELL IJAYO. PRODD9 (ICU. FT. ON GAS (If drilling, depth; if shut down, cause; CTiD I BARRELS OF OIL I CiRA�ITY I �'sASOLI\F. NATER (II n t}lotlS Uuis) ( date end rn9ult of cast for gasoline I RE(:oti �:it%D I tlnllC, ;O Shue) content of gas) SC 14 (23) I Ra 2 7/8" tubing,llanded @ 10,658!. Removed BOPEjand installed X- s tree. Tested w/5000#. Held OK. Ran CollariLog and perforated with 4 1/2" holes per foot, the intervals: 10'6741 - 10,6841 and 10,7081 - 10,750,. Flowed well. Representative flow ratios: 432 BD/Oil, 87 MCF/D Gas, 8/i It Bean, 1440 T.Pa, 1190 Csg. Press. 55; -rap press. O,�% Total Cut, 0.2% water, 0.2% amulsion, Corr. Gravity 3*4. Rig released 8-2-61. �i I I 1 � •S• .S. Me He Scyster las a 0 G QC - E. D. Bruce ichfield - C We Perry, R. R ilea: P odu ing plo atiorl L nd I It– 0_1 i%–F r - 8r.s.f j 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 appiicahie.) NOTE.—Rep ort on this form is required for each ct lcnclar Iitonth, regardless, of the sit,h s Df I-:peraLions, and must be filed in duplicate with the supervisor b, the Oth of tl.a succe�,ciing nlonth, ur:loss oth:.1r%vise direct_,? t Y the stipervi,,or. Form 9-329 It:--0,-,7CC-8 U. S. ,. VCRNNENT PRINTING CFFI::F, (January 1980) UNITE® STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-8356.5. Approval expires 12-31-60. LAND OFFICE - _-- Anchorage -._,._ LEASE NUMBER__ A-028937 --.------ UNIT --------5Q1d0'tM1. Creek ----- LESSEE'S MONTHLY REPORT OF OPERATIONS Stacie---.--=A:l.�.s}58.------- - -- G'ou.nt� Iii=��__����"'Lt- - --- �ieZd---------�'wa�1�9�_A�VeS'------ ---- ---- ------------ State -- -- The folloivine is a correct I•eport of operations. and produetion (including drilling and producing - -. 1';�. ,----------SQ�_dQt, Ixe} U�3.t wells or the month of __________- s��-Y--- -- - L J f Sf�� - O�' �A�1F'�R��1IA ,lee -nit's address __ _ ', 0- Doi: 7-839 Cofn,p<<r,ft e !J l� -----------._ ._ .-- _ Anc: hfl�.g�, b ls.r. - -- Sinecl �l Phone _. --------- a laxLiendent-Alaska SEC. AtiD Twr SRA C,�' GALL()\3 lF I I)AItHFLS OF I 1ti'`1:1ItkS '% 1-1;. DAYS (� CL ?'. OF (sA9 I (t I I "VATER (11 i_1P.IiiLi oI' OIL C.RA=- 1 1 lat, n l :. iil ,f r.9 t. far R+uulin, No. „,crn' (1Tl Lhn 7aai F �� ;Gd!^1 ?g OF { ±Yr i t .' . ,..:1 ural „f lCt,n) i i 7N (9W - 00t . Dri.11ed 8 I" hole 00 -7.95751. Drilled 10 5/5" isoie 7,193 7, 3 2 7, 3 Rani IES and Sonic log 7,575 - 2, 002' . Opened �" hole to 10 5/8" 700 - 7,5751• Drilled 10 5/81thole 7,575 - 10,8501. Circulated. S4 1Attremted to xuntgs. Could not due to bridges at 9)0001. Went f in !with bit, cond:i.tion�ed mud and. circ. Ran YES lU, 850 - 7, 556' . ' Sonic 10,844 - `7, 565' and Micro 10, 850 - 1Q.,100' - fan I1'Spmeter 10,050 - 210021 i I I Cemented; 7" casing at 1a, (3501 with 1900 sadks cement. 700 sacks aro Oce and 1200 sadks through D.V. at 7, 980' . Rau WSO Test ► ' ! at 1G)61$' . OK* gilled out cement to 10,798", RO-n WSO rPest at 10.9756,.: OK. LGE: I.S. 1e *S* M. , H. Shyster et 01& G CC w gyp. D. Bru iel - C. W. Perry, R. Producing roaaad Ritter 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.) NOTE.—Report on this form is required for each calendar month, regardless of the stabis 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 16-25769-8 U. S. GOVERNMENT PRINTING ormi! (January 1950) Form 8-7818 (Feb. IWI ) -----,---- ----- X (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No.12-11368,4. Approval expires 1Z -31-W. Land O!!ke _ Anchorage - Lease No. 0;a&_. .L ------------- Unit _ 'saida_ . Cxa0lc,.- SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO DRILL_ ____---____-______.- NOTICE OF INTENTION TO CHANGE PLANS ._ NOTICE OF INTENTION TO TEST WATER SHUT-OFF_ NOTICE OF INTENTION TO RE -DRILL OR REPAIR WELL NOTICE OF INTENTION TO SHOOT OR ACIDIZE____- --- NOTICE OF INTENTION TO PULL OR ALTER CASING.__ . NOTICE OF INTENTION TO ABANDON WELL -------------- ------------------------------------- X . SUBSEQUENT REPORT OF WATER SHUT-OFF_ .. _.... _ ____ SUBSEQUENT REPORT OF SHOOTING OR ACIDIZING SUBSEQUENT REPORT OF ALTERING CASING___ _ __ SUBSEQUENT REPORT OF RE -DRILLING OR REPAIR. SUBSEQUENT REPORT OF ABANDONMENT_ __ _ _ _ . _ . . SUPPLEMENTARY WELL HISTORY_ _ __-_._..._____--__. (INDICATE ABOVE BY CHECK MARK NATURE OF REPORT, NOTICE, OR OTHER DATA) June -9 --------------------------------- 19.61 SC. 14-_ Avpx�oximately l Well No. _ ____. _____3__ is located l X50_ ft. from__ 1 } line and ___ 099.- ft. from ft line of sec. _3-_____-_ lj - -5iw Seward---- - --_- _ (Y4 Bee. and See. No.) (Twp.) (Range) (Meridian) Svanson River Kenai Peninsula Alaska - - - -- -- --------------- - -------- - ------------ --- - -------------------- (Field) (County or Subdivision) (State or Territory) K.B. The elevation of the �tttoc above sea level is _ ._149 --- ft. aprproximatelye DETAILS OF WORK (State names of and expected depths to objective send*=show sizes, weights,, and lengths of pro _j casings= indicate mudding jobs, cement - Ing points, and all other important proposed work) 1. Drill to 2000' and cemenv 11 3/4" casing to surface. 2. Install and teat Class III Blowout Preventioli Equipment. 3. Drill -Lo approximately 74W', toand test. 4. Drill ahead to approximate],y•10, 50' log and cement 7" casing in tea stages. 5. Reinstall and test Class III Blowout Prevention Equipment. Drill out and test D. V. collar. 6. Establish requisite water smut -offs. 7. Selectively jet perforate attractive sande. 8. Fan 2 7/8" tubing and complete. I understand that this plan of work must receive approval in writing by the Geological Survey before operations may be commenced. CompanyJD__OIL__GCHI AICY__OF__CALIFQRRNIA,_---------------------- Address -----p----0' -Box 7 _39 --------- Anchcara Ahaska By Title District Serintendent-Alaska Ore 6411040 ,I Budget Bureau No. 92- 8356.5. Approval expireq 12--31-W. UNITED STATES LAND OFFICE -____Anchorage_ --- _ DEPARTMENT OF THE INTERIOR LEASE NUMBER -_ 4_-02899'x-___-_-_--_-- f'-EOLO1-_ICA1 SURVEV UNIT -------- &old.otin&__Crl9ek_----- LESSEE'S MONTHLY REPORT OF OPERATIONS )State _______-__Alaska________-.-- County Kenai Peninsula-_____ Field -----____--Swanson River The following is a correct report of operations and production (includin6 drillin.6 and producing wells) for the Month of ---------------J- u-Ae -- ----------_-..._._, 1�1__ Soldotna Creek Unit ----- ----------------- .4eent's address ------- 7439______ ---- -------------- Company-_STAIDARD 0IL CO. OF CALIF RNIA Western-" : at ons -- nc ------------ ---- ---- :- -- - -Anchorage,, .Ala--ska -- - --.__ sh"71.ed � I3Roadwa °.6201 :� a � ; t, ),, C , V C TON IK Supt. ------------ Phone --- --- ---------------------- --------------.------------ _ '8=. AN -D` �' �I Wx f. a T1AY 8 ' � L?. FT. OF ("As L� a'IIG - )1 I ;'9 Or � f � i lit h. `Pti'F. Nis nAATt%js of OIL (CiItAV 1i' CAS+ 1 A,,,, (I.( (I i.Illinr i a+.,+: if gut ,Iowa cruse; i;0. { Plco,�r+:e�: t f 17t tIIOU il(.S) ( -(?}CU1 ,..t '> 1 ,. :(•, 5(� `�13f��) 1 +i..'e tin I �+ ult ni 6,t for Sou 14-3 (23) l dded 6-1661. !Drilled 16" hole 0 - 20301110 Cem6nted 11-3/4" ing 0 2002', w/1350 (sacks. Drib led 10 K/811 hole 20301 - 7 Vo Stuck driT1 pipe 3180' when comIng out o� hole. Worked stuck pipe for; 60 hrtso Recovered stuc;l nipeo Grilled 71 — 719340 ! a I 3 7N1 9W I S i � c SWC i 3 S o NOTE.—'Where were ______________________________________ runs or sales of oil, ---------------------------------------------- M cu. ft. of gr -s sold; --------------------------------------------- runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.—Report on this form is required for each calendar month, regardless of the status of operations, and Inust be ii.led in duplicate with the supervisor by the 6th of the succeeding morph, unless otherwise directed by the superVisor. FDrm. 9-328 (January 1850) 1G --2576n 8 U. S. GOYFRNM[NT i NINTIN . OFFICE r APPLICATION FOR' PERMIT TO DRILL, DEEPEN OR` PLUG BACK APPLICATJ:ON, TO DRILL _ ..v 'S DEEPEN Q PLUG BACK Q NAME OF COMPANY OR OPERATOR DATE Address City. '. State 04 v D#hSCRIPTION OF WELL AND LEASE Name of lease Well number Elevation (ground) aMW-W—► Well location (give otag4 from section lines) Section—township—range or block & survey z , Field & reservs r (,If.e%v ldcat,; so state) Vic, {County awl 11 11 Mom is, *Oor Distance, in miles, 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: feet feet Proposed depth-. I Rotary or cable tools Approx. date work will start I Number of acres in lease: Number of wells on lease, including this well, completed in or drilling to this reservoir: If lease, purchased with one or more Name Address wells drilled, from whom purchased: 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 th i I of the l I i �' I' (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. Original Signed C. V. CHATTENTON Signature O Vo Permit Number: Approval Date; J 22# Approved By: Cuef F"` Notice: Before sending in this form be sure that you"have given all information requested. Much 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 Ask.— OW144 *OR imp s0 wt -vu 449 a ou Ifto u- wa I �- z "'
