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Home My WebLink About161-010 • •(oc3Loo Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, October 08, 2015 11:11 AM To: Donna Ambruz Cc: Chad Helgeson;Carlisle, Samantha J (DOA) Subject: RE: Sundry Cancellation - Sundry#314-541 - SRU 21-27 (PTD 161-010) Donna, AOGCC will withdraw sundry 314-541 as requested. Scope of work was pull ESP and run Gas lift design on SRU 21-27. Guy Schwartz Sr. Petroleum Engineer AOGCC sante) , s, i, 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Donna Ambruz [mailto:dambrurt thilcorp.com] Sent: Thursday, October 08, 2015 9:29 AM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson Subject: Sundry Cancellation - Sundry # 314-541 - SRU 21-27 (PTD 161-010) Guy, Please withdraw the above mentioned sundry. Thank you. Donna ainfouvz Operations/Regulatory Tech Kenai Asset Team RBDMSc OCt 13 70li Hilcorp Alaska, LLC �-� 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 907.777.8305-Direct 907.777.8310- Fax dambruz@hilcorp.com 1 THE STATE Stan Porhola r 7 GOVERNOR SEAN PARNELL Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 21-27 Sundry Number: 314-541 Dear Mr. Porhola: Alaska Oil and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this day of October, 2014. Encl. Sincerely, CathyFoerster Chair SCANW UC I I tJ 20"i4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ECEIVEr OCT 0 1 2014 BOG CC 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate [�] , Pull Tubing Time Extension ❑ Operations ShutdovA ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing❑ Other: Pull Failed ESP Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number G` Hilcorp Alaska, LLC Exploratory ❑ Development L11 Stratigraphic ❑ Service ❑ 161-010 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 50-133-10155-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 1236 Will planned perforations require a spacing exception? Yes ❑ No ❑ Swanson River Unit (SRU) 21-27 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 ' I Swanson River Field / Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,142' 11,142' 11,000' 11,000' 1 N/A 10,OOT (cut tubing) Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 40' 40' Surface 2,029' 11-3/4" 2,029' 2,029' 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3# 1 L-80 9,764 Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Tripoint AS1-X; N/A 10,01 T MD & TVD; N/A 12. Attachments: Description Summary of Proposal ❑� 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic❑ Development n Service n 14. Estimated Date for - 15. Well Status after propsed work: Commencing Operations: 10f01�` Oil 0 Gas ❑ WINJ ] GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sporhola@biLicorp.com Printed Name Stan Porhollaaa Title Operations Engineer Signature ` Phone 907-777-8412 Date U t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30-6q) Plug Integrity ❑ BOP Test li;K Mechanical Integrity Test ❑ Location Clearance El4(-lI Other: ?&Z rOS� SOP /GJ 1 - ( /A(+ /0 = V/SL) Spacing Exception Required? Yes ❑ No Subsequent Form Required: d - Li diy APPROVED BY Approved by: �� - COMMISSIONER THE COMMISSION Date: �� 1 */./,( Submit Form and F r 10- 0 ew d tQ Approved applicatiois TR Ir 1 `lt ALdate of approval. Wachments in Duplicate HilcorP Alaska, LLQ Well Prognosis Well: SRU 21-27 Date:10/01/2014 Well Name: SRU 21-27 API Number: 50-133-10155-00 Current Status: ESP Oil Well Leg: N/A Estimated Start Date: October 7`h, 2014 Rig: Moncla #401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 161-010 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure Brief Well Summary 2,500 psi @ 10,748' TVD 2,500 psi @ 10,748' TVD 0 psi (Static pressure Aug 2013 based on ESP sensors mid perf of 10,748' MD) (Static pressure Aug 2013 based on ESP sensors mid pert of 10,748' MD) (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 4,255 ft. TVD. This well was drilled and completed as an oil well in Hemlock benches H-1 thru H-5 in 1961. A workover performed in 1962 pulled the existing completion, made a cleanout run, and ran a new completion. A workover in 2009 attempted to pull the completion but left some of the original 1962 completion in the well. A workover performed in 2012 removed the new tubing and packer, was able to recover the older existing packer, reperforated selected zones in the Hemlock and ran a new gaslift completion. The Tyonek G zone was perforated thru-tubing in 2013. An ESP was installed in August 2013. While producing, the ESP experienced issues with solids/scale that led to daily shutdowns of the ESP and an increased rate of gas also affected ESP performance. The ESP was replaced in December 2013 and placed on production and recently failed. Notes Regarding Wellbore Condition • ESP is currently down (likely failed due to downhole motor or pump failure). WO Rig Procedure: 1. MIRU Moncla #401 WO Rig. 2. Set BPV. ND Tree. 3. NU 7-1/16" BOPE. Set BPV. Test to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 1,500 psi High (hold each valve and test for 10 -min). Record accumulator pre -charge pressures and chart tests. Notify AOGCC 24 hrs in advance of BOP test. Notify BLM 48 hrs in advance of BOP test. 4. Bleed any pressure off tubing. Pull BPV. 5. Kill well w/ 8.4 ppg lease water. 6. Back out tbg hanger hold down pins. 7. MU 3-1/2" landing joint and pull tubing hanger free. 8. SOOH and rack back the 3-1/2" tubing. Lay down the failed ESP Pump. Well Prognosis Well: SRU 21-27 HileorP Alaska, LL SIL Date. 10/01/2014 a. Summit to send ESP components in for tear down analysis (including cable). b. Spool up the dual flat pack and tri -pack and send to CIFO for storage (may be junk). c. Send cannon clamps to CIFO for storage (may be junk). d. Junk the control line bands (total of 1,068 in the well). e. Send the 3-1/2" tubing hanger to CIFO for cleaning and redress. f. Tubing is 3-1/2" 8RD (100% Tensile = 207k). g. Send 3-1/2" GLM to Pollard for cleaning and redress. -RU Slickline. 10. RIH w/ junk basket and fish out lost bands. 11. RD Slickline. 12. PU overshot w/ 3-1/2" grapple and jars. L, 13. RIH and engage jet cut tubing at 10,007'. Attempt to jar packer free% /0 Or7 Alk a. If packer comes free, POOH. L/D fish. b. If packer does not come free, disengage fish. POOH. L/D overshot and jars. 14. PU 7" 29.0# casing scraper and 6" bit. a. Drift diameter of casing is 6.184". 15. RIH w/ 6" bit, casing scraper w/ 3-1/2" 8RD tubing to 10,768' to current PBTD. 16. Cleanout soft fill to 10,810' or as deep as possible. 17. POOH. Lay down casing scraper, bit, and rack back the 3-1/2" tubing. 18. PU completion jewelry and hydraulic packer. 19. RIH and set packer at +/- 10,568' MD. a. Leave tubing tail to land +/- 30' above top perfs at 10,633'. b. Use conventional bands to secure chemical injection line to tubing. c. Space out Gaslift Mandrels per proposed schematic. d. Pre -load X -profile with RHCP plug body. . e. Run dummy valves in all Gaslift Mandrels.- f. andrels:f. Run dummy valve in Chemical Injection Mandrel. 20. Drop RHCP ball and rod. Pressure up to 3,500 psi and set hydraulic packer. 21. Test tubing to 3,500 psi for 30 min and chart. 22. MIRU Slickline. 23. Pull RHCP ball and rod. RD Slickline. 24. Test casing to 2,500 psi for 30 min and chart. s1 25. Lay down landing joint. Set BPV. ND BOPE. NU tree. Pull BPV. 26. Set TWC. Test hanger to 250/3,500 psi. Test tree to 250/5,000 psi. Pull TWC. 27. RD Moncla #401 WO Rig. 28. Turn well over to production in preparation of moving off the Moncla #401 WO Rig. 29. Replace IA x OA pressure gauge if removed (7" x 11-3/4"). Slickline Procedure: 1. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 2. RIH and pull dummy valves from each gaslift mandrel (6 mandrels). POOH. 3. RIH and pull dummy valve from the chemical injection mandrel. POOH. 4. RIH and set live valve in chemical injection mandrel. POOH. a. Set spring pressure to 3,000 psi. 5. RIH and set live valves in each gaslift mandrel (6 mandrels). POOH. Well Prognosis Well: SRU 21-27 Date: 10/01/2014 6. RIH and pull RHBC plug body from X -profile. POOH. 7. RIH w/ 2.5"x20' dummy gun to PBTD. a. Well is vertical. Pine Procedure: 8. MIRU E -line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 9. RU 2.50" 6 spf HC wireline guns (will make multiple runs, 20' guns, 6 spf shot density). 10. Bleed tubing pressure down to below 150 psi, as directed by Reservoir Engineer. 11. RIH and perforate the following intervals: 12. Hemlock H -4/H-5 from 10,778'-10,805' (27') (2 runs, total of 6 spf). 13. Hemlock H -2/H-3 from 10,708'-10,773' (65') (4 runs, total of 6 spf). 14. Hemlock H-1 from 10,676'-10,703' (27') (2 runs, total of 6 spf). 15. Tyonek G from 10,633'-10,653' (20') (1 run, total of 6 spf). a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using GR/CCL dated 9/21/12. (Tie-in log depth same as schematic). d. Record tubing pressures before and after each perforating run. e. No Spacing allowance required, per CO 1236, no spacing limits in Hemlock/Tyonek G. 16. RD E -line. 17. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic 11ilrorp Alaska, LLA. 21r'4 113/ TOF 10,71 151 con bob unk RKB = 19' GL -18N ACTUAL SCHEMATIC CASING DETAIL Swanson River Unit Well SRU 21-27 Completion Ran: 12/19/2013 PTD: 161-010 API: 50-133-10155-00 Size WT Grade Conn ID Top Btm 20" - Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 40' 11-3/4" 47 J-55 8RD 11.00 Surface 2,029' 9,690' 29 P-110 BTC 6.184 Surface 160' 1 4.000" 26 N-80 BTC 6.276 160' 1,091' 7 23 N-80 BTC 6.366 1,091 4,783' 7„ 26 N-80 BTC 6.276 4,783' 6,583' TripointT-2 On/Off Tool 29 P-110 BTC 6.184 6,583' 8,398' 10,031' 29 P-110 8RD 6.184 8,398' 11,142' TUBING DETAIL 3-1/2" 9.3 L-80 I EUE 8RD 1 2.992 1 Surface 1 9,764' JEWELRY DETAIL No Depth ID OD Item 1 19' 2.992" 6.184" Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 3.500" XO, IBT Pin x EUE 8RD Pin 3 7,518' 2.992' 5.313" GL SFO -1 Mandrel, Dummy Valve 4 9,690' 2.992" 5.313" GL SFO -1 Mandrel, Dummy Valve 5 1 9,764' - 1 4.000" Top of Summit ESP, Discharge Head 6 9,854' - 4.000" ESP Intake 7 9,906' - 5.520" Base of ESP, 456 series Motor / 400 series Pumps 8 10,007' 2.992" 3.500" Jet Cut Tubing, 3-1/2" 9 10,016' 2.813" 5.750" TripointT-2 On/Off Tool 10 10,017' 3.000" 5.875" Tripoint AS1-X packer 11 10,031' 1 2.660 3.900" XN Nipple 12 10,032' 1 3.000 4.125" WL Entry Guide PERFORATION DATA Zone Cable/Clamp/Band Detail 9,871' - 9,906' 7 ea 4560 Cannon Clamps (Re -used clamps; Across Motor Only) 9,764'- 9,871' 20 ea 4010 Cannon Clamps (Re -used clamps; Across Pumps/Gas Handler) 0'- 9,764' 3 ea %" SS bands per tubing joint (additional 1 ea for flatpack every other joint) Notes (SUMMIT ESP INSTALLED 12/19/13) 0'- 9,750' 1 ea Reda #i2 Flat ESP Cable (Splice depths at approx. 35', 2,950', and 8,450') 9,750' - 9,871' 1 ea MLE Flat Cable 0'- 9,754' 1 ea Dual Flatpack Encapsulated Control Lines (2 ea Chem Inj) 9,754'- 9,906' 1 ea Tri Flatpack Encapsulated Control Lines (2 ea Chem Inj, 1 ea Phoenix) PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes G 10,633' 10,653 10,633' 10,653' 6 1/31/13 Open 2-1/8" 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SOZD H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Oen 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" 10,708' 1 10,768' 10,708' 1 10,768' 1 6 9/23/2012 1 Open 3-3/8" H2/H3 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open H4/H5 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Oen TD =11,142' PBTD =11,000' Directional Data: max hole angle = 2.25° at 2,035' MD 7" Cement Bond Lo¢ 10,195'- 10,280' Good 10,365'- 10,432' - Fair 10,575'- 10,604' Good 10,675'- 10,710' - Fair Downhole Revised: 12/19/13 Updated by STP 1/06/14 Swanson River Unit Well SRU 21-27 PROPOSED SCHEMATIC PTD Completio161-010n Hileurp Alaska, LLC API: 50-133-10155-00 20" 0 113b 15f CUT batt unk T' RKB=19 CASING DETAIL GL =184' Size WT Grade Conn ID Top Btm 20" - Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 40' 11-3/4" 47 1-55 8RD 11.00 Surface 2,029' 5,500' 29 P-110 BTC 6.184 Surface 160' 5.250" 26 N-80 BTC 6.276 160' 1,091' 7 23 N-80 BTC 6.366 1,091' 4,783' 7„ 26 N-80 BTC 6.276 4,783' 6,583' Chemical Injection Mandrel 29 P-110 BTC 6.184 6,583' 8,398' 10,589' 29 P-110 8RD 6.184 8,398' 11,142' TUBING DETAIL 3-1/2" 9.3 L-80 I WEND 1 2.992 1 Surface 10,600 JEWELRY DETAIL No Depth ID OD Item 1 19' 2.992" 6.184" Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 3.500" XO, IBT Pin x EUE 8RD Pin 3 3,500' 2.992" 5.250" GL SFO -1 Mandrel, GLV #6 4 5,500' 2.992" 5.250" GL SFO -1 Mandrel, GLV #5 5 7,300' 2.992" 5.250" GL SFO -1 Mandrel, GLV #4 6 8,900' 2.992" 5.250" GL SFO -1 Mandrel, GLV #3 7 10,000' 2.992" 5.250" GL SFO -1 Mandrel, GLV #2 8 10,500' 2.992" 5.250" GL SFO -1 Mandrel, GLV #1 Orifice 9 10,550' 2.992" 5.250" Chemical Injection Mandrel 30 10,568' 3.000" 5.875" Hydraulic Packer 11 10,589' 2.813" 4.500" X Nipple 12 10,600' 3.000" 4.500" WL Entry Guide PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes G 10,633' 10,653 10,633' 10,653' 6/6 1/31/13 Open 2-1/8" 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD H1 10,676' 10,696' 10,676' 10,696' 4/6 5/4/1961 Open 10,683' 10,703' 10,683' 10,703' 6/6 9/22/2012 Open 3-3/8" 10,708' 10,768' 10,708' 10,768' 6/6 9/23/2012 Open 3-3/8" H2/H3 10,710' 10,773' 10,710' 10,773' 4/6 5/4/1961 Open H4/H5 10,778' 1 10,805' 10,778' 10,805' 4/6 5/4/1961 Open TD =11,142' PBTD =11,000' Directional Data: max hole angle = 2.250 at 2,035' MD 7" Cement Bond Log 10,195'- 10,280' Good 10,365'- 10,432' Fair 10,575'- 10,604' Good 10,675'- 10,710' Fair Downhole Proposed Updated by STP 10/01/14 2 1/16 IOM Kill Valves Manual and HCR Swanson River 2014 Moncla Rig 401 Knight Oil Tools BOP 2 3/8-3 % variable 2 1/16 1 O Choke Valves Manual and HCR STATE OF ALASKA E ` AL A OIL AND GAS CONSERVATION COMMISSION JAN 0 6 Z014 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other UReplace ESP Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac EI Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development .❑ Exploratory ❑ , 161-010 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 • 50-133-10155-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 - Swanson River Unit(SRU)21-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured . 11,142 feet Plugs measured N/A feet true vertical 11,142 feet Junk measured 10,768(fill) feet Effective Depth measured • 10,768 feet Packer measured 10,017 feet true vertical 10,768 feet true vertical 10,017 feet Casing Length Size MD ND Burst Collapse Structural Conductor 40' 20" 40' 40' Surface 2,029' 11-3/4" 2,029' 2,029' 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached Schematic -SCANNED MAY 2 7 2014 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,968'MD 9,968'ND Packers and SSSV(type,measured and true vertical depth) Tripoint AS1-X 10,017'MD 10,017'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A RBDM MAY 16 2014 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 56 396 452 250 1300 Subsequent to operation: 86 693 778 175 400 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑r • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil• I=1 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-548 Contact Stan Porhola Email sporholan.hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature `,�� — Phone 907-777-M12 Date IA 6fr. f) 5---2Z-/LI Form 10-404 Revised 10/2012 4. 5"/��y Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 21-27 50-133-10155-00 161-010 12/14/13 12/20/13 Daily Operations: 12/14/2013 -Saturday MIRU Moncla 405. Spot pump, tanks, and choke/kill manifolds. RU winterization. Spot accumulator and wire generators. Raise derrick. Continue RU while blowing down tubing, some fluid returns and not bleeding off. Pump 72 bbls fluid down tubing and went on vacuum. Monitor well -well dead. No pressure on casing. Set BPV and ND tree. NU BOPE and raise rig floor and install tarps. Prep to test BOP. 12/15/2013-Sunday Worked on repairing power cable for Koomey Unit, Shell tested BOPE to 3,000psi. Tested BOPE,Annular 1 500_250psi, Valves 3,000-25Qp i Rams 3,000-250psi. Recorded one failure on C3. Greased C3 and tested-pass. Witness waived by Jim Regg, AOGCC. Sealed in contaiment and RU SLB equipment. Pumped 20bbls down tbg and pulled BPV, opened up casing valve and found ice plug. Thaw plug and annulus had 1000+psi. Pump 171 bbls down annulus and went on vacuum. Check tubing and found pressure, pump 45 bbls down tubing and went on vacuum. Casing pressure-650 psi. Pump 355 bbls down tubing, bleeding pressure on casing while pumping. Bled to zero - monitor casing and tubing-dead. Pull hanger and LD landing joint, RD penetrator and control lines. One control line had pressure, possible leaking check valve. LD single and pup joint. RU sheaves. _POOH w/ ESP on 3-1/2" tubing. 12/16/2013 - Monday Continued SOOH with 3-1/2" tbg and Schlumberger ESP. RD spools and RU to PU BHA. MU 5.75" overshot (w/o grapple), bumper jars, oil jars, and (6) 4.75" DC's. RIH w/overshot on 3-1/2" tubing. PU 4 singles and tag fish @ 10,005' MD RKB. RU Pollard slickline. RIH w/ 1.75" bailer and set down @ 10,073' wlm rkb. WT and fell through. Tag fill @ 10,855'. Attempt sample. POOH. OOH - nothing in bailer. Depth counter on unit appears to be running deeper than actual. RD Pollard. Begin jarring on fish, attempting to push to bottom. 12/17/2013-Tuesday Jar on fish w/5.75" overshot. Continue jarring. 10K lbs hits- no movement, 15K lbs hits- no movement. 25K lbs hits- no. Decision to leave fish and run ESP. LD 4 joints and SOOH w/overshot on 3-1/2" tubing. LD DC's and fishing BHA. RU Summit to run ESP equipment. Found short on previously run ESP flat cable, cut off several sections and still shorted. Swap for spool of new cable. Splice on MLE. Prepare to PU ESP. MU ESP motor assembly arid_fill_with oil._Change out tripack spool. Issues with compressor starting. Thaw spooler to get operating. Connect tripack control line to motor assembly. 12/18/2013 -Wednesday Continued MU Motor section and Pump section. MU XO and TIH with the ESP, 3-1/2" EUE , (2) 3-1/2" GLV loaded with dummy valves. Swap spools and splice @ '"8,450' (final depth). Continue RIH w/ ESP on 3-1/2" tubing. Swap spools and splice @ —2,950' (final depth). 12/19/2013 -Thursday Continued RIH w/ESP and 305 jts of 3-1/2" EUE L-80 8RD tbg w/(2) 3-1/2" GLM and a 5.61" pup jt. MU Tbg Hngr on a full jt. Measured and cut the control lines. MU swedge fittings and ran contol lines thru Hngr. Tested good. MU Penetrator and made pig tail splice. MU landing jt and landed Tbg Hngr with 83k in string weight. Secured lockdown pins and set the BPV. ND the BOP's and NU the PT. Tested to 5,000psi -good. RD WOR and cleaner area around the wellhead. w III Swanson River Unit Well SRU 21-27 ACTUAL SCHEMATIC 1161010Ran: 12/19/2013 PTD: Hileorp Alaska,LI.4 API: 50-133-10155-00 RKB=19' CASING DETAIL GL=184' 11 ' Size WT Grade Conn ID Top Btm 2 A 20" 40' 1� 11-3/4" 47 J-55 8RD 11.00 Surface 2,029' 20"fp40' 29 P-110 BTC 6.184 Surface 160' ,4, 26 N-80 BTC 6.276 160' 1,091' r.; r 7„ 23 N-80 BTC 6.366 1,091' 4,783' 26 N-80 BTC 6.276 4,783' 6,583' 29 P-110 BTC 6.184 6,583' 8,398' 4 b. 29 P-110 8RD 6.184 8,398' 11,142' 11-3/4"@z,o29' TUBING DETAIL 3-1/2" 9.3 L-80 EUE 8RD 2.992 Surface 9,764' JEWELRY DETAIL No Depth ID OD Item 1 19' 2.992" 6.184" Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 3.500" X0,IBT Pin x EUE 8RD Pin 3 7,518' 2.992" 5.313" GL SFO-1 Mandrel,Dummy Valve 3 4 9,690' 2.992" 5.313" GL SF0-1 Mandrel,Dummy Valve ' 5 9,764' - 4.000" Top of Summit ESP,Discharge Head 6 9,854' - 4.000" ESP Intake 7 9,906' - 5.520" Base of ESP,456 series Motor/400 series Pumps 8 10,007' 2.992" 3.500" Jet Cut Tubing,3-1/2" l d 4 9 10,016' 2.813" 5.750" Tripoint T-2 On/Off Tool 10 10,017' 3.000" 5.875" Tripoint AS1-X packer 11 10,031' 2.660" 3.900" XN Nipple 5 IMMIX 12 10,032' 3.000" 4.125" WL Entry Guide �- 6 IIMMIIIIK Cable/Clamp/Band Detail 8 9,871'-9,906' - 7 ea 4560 Cannon Clamps(Re-used clamps;Across Motor Only) I9,764'-9,871' - 20 ea 4010 Cannon Clamps(Re-used clamps;Across Pumps/Gas Handler) 9 0'-9,764' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) I (SUMMIT ESP INSTALLED 12/19/13) Iil 0'-9,750' - 1 ea Reda#2 Flat ESP Cable(Splice depths at approx.35',2,950',and 8,450') - ' 10 9,750'-9,871' - 1 ea MLE Flat Cable 0'-9,754' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) ii -m 9,754'-9,906' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) 12 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes TOF tagged @ -G G 10,633' 10,653 10,633' 10,653' 6 1/31/13 Open 2-1/8" 10,768'-9/22/12 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD =H-1 H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open `H-2/H3 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" Halls H2/H3 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3-3/8" 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open 15 ft of original _ H4/H5 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Open completion left in _ . bottom of well, • unknown depth T'@11,147 �. .. ' - ', 7"Cement Bond Log 10,195'-10,280' - Good TD=11,142' PBTD=11,000' 10,365'-10,432' - Fair Directional Data: 10,575'-10,604' - Good max hole angle=2.25°at 2,035'MD 10,675'-10,710' - Fair Downhole Revised: 12/19/13 Updated by STP 1/06/14 . STATE OF ALASKA � • AL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Annular Flow Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development IO Exploratory ❑ 161-010 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10155-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 Swanson River Unit(SRU)21-27 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/HeAMEIVED 11.Present Well Condition Summary: Total Depth measured 11,142 feet Plugs measured N/A feet NOV 25 2 \ true vertical 11,142 feet Junk measured 10,768(fill) feet (� A G Effective Depth measured 10,768 feet Packer measured 10,017 feet true vertical 10,768 feet true vertical 10,017 feet Casing Length Size MD ND Burst Collapse Structural Conductor 40' 20" 40' 40' Surface 2,029' 11-3/4" 2,029' 2,029' 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner r a n ,'k t, Perforation depth Measured depth See Attached Schematic 7. True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,968'MD 9,968'ND Packers and SSSV(type,measured and true vertical depth) Tripoint AS1-X 10,017'MD 10,017'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 120 125 Subsequent to operation: 57 632 463 250 1200 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development El ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 12 . Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-574 Contact Stan Porhola Email sporholac hilcorp.com Printed Name / Porhola Title Operations Engineer Signature .,. _ Phone 907-777-8412 Date 1 t 3 RBDM`. OV 2 5 .. 7eForm 10-404 Revised 10/2012 1 744' Submit Original Only , ini H . Swanson River Unit Well SRU 21-27 • ACTUAL SCHEMATIC Com le ion Ran:08/30/2013 Ililcorp Alaska,LLC API: 50-133-10155-00 RKB=19' CASING DETAIL GL=184' 1 I 1 -A Size WT Grade Conn ID Top Btm 2 20" - - - 40' T> 11-3/4" 47 J-55 8RD 11 Surface 2,029' 20'@40 ,, 29 P-110 BTC 6.184 Surface 160' 26 N-80 BTC 6.276 160' 1091' ,' 23 N-80 BTC 6.366 1091' 4783' ;'F4 t 7 26 N-80 BTC 6.276 4783' 6583' +. 29 P-110 BTC 6.184 6583' 8398' III is`; 29 P-110 8RD 6.184 8398' 11,142' 113/4"@2,029' TUBING DETAIL 3-1/2" I 9.3 I L-80 I EUE 8RD I 2.992 I Surface I 9,764' JEWELRY DETAIL No Depth ID OD Item • 1 19' 2.992" 6.184" Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 3.500" X0,IBT Pin x EUE 8RD Pin 3 7,518' 2.992" 5.313" GL SFO-1 Mandrel,Dummy Valve 4 9,690' 2.992" 5.313" GL SFO-1 Mandrel,Reverse Gaslift Valve S 9,764' - 4.000" Top of ESP,Discharge Head 1". 6 9,968' 5.520" Base of ESP,456 series Motors/400 series Pumps 7 10,007' 2.992" 3.500" Jet Cut Tubing,3-1/2" 8 10,016' 2.813" 5.750" Tripoint T-2 On/Off Tool ea i' 4 9 10,017' 3.000" 5.875" Tripoint AS1-X packer 10 10,031' 2.660" 3.900" XN Nipple 5 11 10,032' 3.000" 4.125" WL Entry Guide Cable/Clamp/Band Detail 6 9,901'-9,968' - 8 ea 4560 Cannon Clamps(Across Motors Only) 7 9,763'-9,901' - 18 ea 4010 Cannon Clamps(Across Pumps/Gas Handler) 9,733'-9,763' - 9 ea%"SS bands(all on 1st joint above discharge head) I I 8 0'-9,733' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) I t t t 0'-9,781' - 1 ea Reda#1/#2 Flat ESP Cable(Splice depths at approx.35',5,000',and 9,781') 9 9,781'-9,933' - 1 ea MLE Flat Cable(Splice depth at approx.. 10,381') sow «3 0'-9,744' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) 10 int .. Mt 9,744'-9,968' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) 11 =. PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes TOFtagg l@ --C' G 10,633' 10,653 10,633' 10,653' 6 1/31/13 Open 2-1/8" 19768-9/22/12 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD =H-1 H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open --H-2/H3 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3-3/8" ` ?-` H-4/H-5 H2/H3 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open 15ftofongnal r H4/H5 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Open completion left in "f bottom of well, >+. *e,* g._: unknown depth y t 4c 7 @11,142 ? - " 7"Cement Bond Log 10,195'-10,280' - Good TD=11,142' PBTD=11,000' 10,365'-10,432' Fair Directional Data: 10,575'-10,604' - Good max hole angle=2.25°at 2035'MD 10,675'-10,710' - Fair Downhole Revised:10/11/13 Updated by STP 11/19/13 • I w\o ��j_s THE STATE Alaska Oil and s h „ALASKA® Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue *R' OF ALAS.";:e*F+ Anchorage, Alaska 99501-3572 Main: 907.279.1 433 Fax: 907.276.7542 Stan Porhola Operations Engineer scoNEfl Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 0 Anchorage, AK 99503 I fn �' Q Re: Swanson River Field, Hemlock Oil Pool, SRU 21-27 Sundry Number: 313-574 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, off t y . oerster air, Commissi• r DATED this day of November, 2013. Encl. 1_ • � s,� STATE OF ALASKA i . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,( 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Annular Flow 1511 - 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Numbe Exploratory ❑ Development E 161-010 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service Ill 6.API Number. - Anchorage,Alaska 99503 50-133-10155-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Swanson River Unit(SRU)21-27 Will planned perforations require a spacing exception? Yes ❑ No E 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 Swanson River Field/Hemlock Oil . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,142' 11,142' 10,781' 10,781' N/A 10,007'(cut tubing) Casing Length Size MD ND Burst Collapse Structural Conductor 40' 20" 40' 40' Surface 2,029' 11-3/4" 2,029' 2,029' 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,764 Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): Tripoint AS1-X;N/A 10,017'MD&ND;N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphifi Development rd Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/04/13 Oil El • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG [] Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email SDOrhola pC�hiICOrD.COCTI Printed Name Stan Porhola jJ / Title Operations Engineer f 7 Signature __fr74/^ Phone 907-777-8412 Date I I V l /3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k3— S`1`i Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4- /4 -r dA,, ..� ,„„t p, zv ,44c z s: zoc (4) F7 C4...) MnT its .erg c�.9 l¢d '� . O Spacing Exception a Nired? Yes ❑ No [ Subsequent Form Required: /Q--�f t"� / rely �id�r5 APPROVED BY Approve by: �A�� r/) .ta COMMISSIONER THE COMMISSION Date: p 6--/3 ��'7'�3 Submit Form and 1 y F 0-403(Re ised 10/2012) App ed application is valid for 12 mo Attachments in Dupli a ,' j.k E9 NOV - 6 RrmarNpril. .4ivo it Hilcorp Alaska,LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 Phone: 907/777-8412 November 1, 2013 Fax: 907/777-8301 Cvw knew 13 EC I D Alaska Oil and Gas Conservation Commission N V 0 1 2013 333 W.7th Ave., Ste. 100 Anchorage,Alaska 99501 AOGCC Re: Swanson River Field SRU 21-27 (PTD 161-010)Request for Annular Flow Dear Commissioner: This letter is to make a request to approve annular flow for well SRU 21-27 and includes the information requested by Guy Schwartz on 10/22/2013. Attached are the documents requested to supply the information needed to approve this request. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, LLC ALL— Stan Porhola Operations Engineer stp 10-403 Form Description Letter MOC Process Form MOC Screening Form MOC Regulatory Screening Form PI&D cc: Chad Helgeson • MOC Process: See the attached MOC documents: 1.) MOC Process Form 2.) MOC Screening Form 3.)MOC Regulatory Screening Form 4.) PI&D SSV Settings: The setting of the SSVs are operationally sensed from the same Hi/Low Pilot. Both SSVs will stay in operation during the annulus flow configuration however the SSV on the tubing side of the wellhead will be blocked in by the two wing valves to direct flow down the tubing. The Hi/Low pilot is set at 900psig/90psig respectively. The SSV on the downstream side of the annulus will be in operation and the HI/LO pilot will remain in operation. Artificial Lift: The artificial lift line to the well can be manually isolated on the pad in several locations. From the wellhead upstream to GL supply we have a check valve, an isolation valve, a choke, another isolation valve, gas lift line heater, another block valve, and finally a block valve on the supply line in the piping corridor. All the piping is rated to 3,000 psig with the check valve rated for 3,705 psig service or greater. We have several places on and off the pad to isolate the gas lift supply. • • Hilcorp Alaska, LLC. : Management of Change ; . Section 1:Background MOC Name: SRU 21-27 Annuluar Flow MOC Initiator: chelgeson Platform/Facility: Swanson River AFE No./Cost Center: 1322090 MOC Number: HAK2013-10-25 465 Date Initiated: 10/21/2013 Section 2:Change Type Duration: (� Permanent r Temporary Dates: From: To: MOC Scope: r Equipment: J Procedural J Personnel Changes J Material Op.Condition Regulated ( " DOT ( ADEC )" ` ADOL p Other: AOGCC System: Reason for Change: ESP Plugged up and will not run. Detailed description of project(Attach supporting documents,PI&Ds,Flow Diagrams,etc...) Attempt to reverse gas lift down tubing and flow well up the annulus to production. 1.The gas lift flowline and gas lift heater must be reconnected to the well. 2.There are tea gas lift mandrels in the well and the plan would be to install a reverse orifice in the lowe,as lift mandrel. 3.The well production would flow to surface and out the casing annuluar valve through an SSV. 4.This would only require one wing valve on the tree to be closed. Dwg. Included? ( " P&ID No.: Equip./Valve Affected: SRU 21-27 Section B initial Authorization/Approval&Team leader Assignment Production Foreman: bhershberger Approved 10/25/2013 Operations Manager: chelgeson Approved 10/25/2013 MOC Team Leader(Assigned by HEC-HOU\bhershberger Foreman:) Upload Attachments o+J File Attachment to Please click on Upload button after choosing a file File name cannot contain special characters like#%& $ :<>?/ Attachment Links File Name Attachment Link 21-27 Anniular Flow MOC Screening.pdf rittu://webaos.hilcoro.co... 21-27 Annular Flow-Regulatory Screening http://webaos.hilcorp.co... Form.pdf 21-27 Annular Flow PID.pdf htto://webaos.hilcoro.co... Section 4:Required Documentation for Closeout No. Record Category Closeout Documents Applicable Person Responsible for Record Record Completion of Record Completed 1. Pre-Construction Regulatory Screening Form(Required for Records(As determined MOC Approval) by MOC Team Lead) Completed HAZAN(if required by Screening Form) 2. Pre-Startup Records(As Pre-start-up Checklist:General • determined by MOC considerations Team Lead) Pre-start-up Checklist:Process/Process r Equipment Pre-start-up Checklist:Equipment/ r Machinery Pre-start-up Checklist:Piping/Valving j' Pre-start-up Checklist:Instrumentation/ r Electrical Pre-start-up Checklist:Structure I 3. Repair/Fabrication Piping Record Form 1- Records(As determined by Inspections) Repair Requirement j nn Material List J Weld Maps Material Certificates/Verification Records I " Welding Procedures&Welder I— Qualification Cert. Non Destructive Testing(NDT)and Reports r Inspections Vessel&Piping Pressure Re-rate (-' Documents Pressure Testing Records/System Service j°' Testing Inspection Visits/Reports r Inspections Hot Tap Records r 4. PSV Modifications Required Capacity Verified/Update PSV r Records(As determined Audit Files by Inspections) PSV Sizing Data Sheet&Supporting r Calculations PSV Quality Control Report(QCR)& r updated files 5. Close-Out Activities(As Updated Drawings(P&IDs, PFDs, Plot ( " determined by PM) Plans,etc.) Updated Flow Measurement Schematics r" Updated NPDES Drawings r Updated or new procedures r Updated SAFE Chart r Provide training for new or modified procedures(DOT,SOP,or SMP),MSDS, Operator Qualifications 6. Other(s) DOT Pipeline Surveillance Form r" Records Review Closed Out By: MOC Team Leader: I Date: Review Section Comments: Sign Off: Sign Off: Facility Engineer approved Approved 10/25/2013 Assigned: HEC-HOU\jkaiser • Approved: jkaiser Production Foreman approved Approved 10/25/2013 Assigned: HEC-HOU\cwalgenbach Approved: bhershberger Environmental OK Approved 10/25/2013 Assigned: HEC-HOU\knixon Approved: knixon Inspections A complete set of UT readings and calculations are Approved 10/29/2013 Assigned: recommended so a current baseline can be in place. HEC-HOU\smorgan Other asset locations have utilized this same Approved: reverse flow and encountered sanding issues smorgan causing accelerated erosion of fittings,especially on direction changes.During this reverse flow operation,follow-up UT readings may be necessary vim` every week or so.Pipe rating for this piping up to �o the SSV's is the G1 Spec.On the gas lift side is the GL Spec(3000 psig).Please file all paperwork with the Inspections Department and call with any questions.This may involve the AOGCC Regulatory Agency:SAMorgan Safety&Training OK Approved 10/28/2013 Assigned: HEC-HOU\m hogge Approved: mhogge Other(DOT Coordinator for approved Approved 10/30/2013 DOT/ADEC Related Projects) Assigned: HEC-HOU\emckay Approved: emckay Instrumentation/Metering OK Approved 10/29/2013 Assigned: HEC-HOU\eoguinn Approved: eoguinn Final Approval(Operations discuss flowing differences with operators to Approved 10/30/2013 Manager,Asset Team understand the safety measures that will need to be Leader or FE Manager) taken if there is an any uncontrolled flow,i.e.no Assigned: master valve. HEC-HOU\chelgeson • • Approved: chelgeson Section 6:Close MOC MOC Team Lead Date: • MOC SCREENING FORM (optional) FACILITY MOC NAME MOC No. Swanson River Unit 21-27 Annular Flow Modification 1. If the proposed change(s) meets any one of the guidelines below,MOC must be employed prior to implementing the work. No Categories Yes No 1. Facilities and Information Appearing on P&ID or NPDES Drawings: p ❑ 1.1 Changes in flowline, pipeline or pipe size, specification or connection. 1.2 Changes to set points on safeguarding instruments (alarms and shutdowns) relating to the safe operating limits. 1.3 Changes in equipment sizing or ratings. 1.4 Permanent removal of CSO or CSC designation on process isolation valves. 1.5 Changes in waste water routing or flow rate 1.6 Changes to any NPDES regulated effluent which include but are not limited to drilling fluids, deck drainage/storm water, sanitary wastes, domestic wastes, boiler blow down, fire control system test water, non-contact cooling water, excess water, flood water, and produced water. 1.7 Installation, changes, or modifications to a well's safety valve system. If yes, review 20AAC25.265 for requirements. 2. Changes in SOP's or deviations from existing specifications for engineering ❑ MI equipment such as pumps, motors, valves, instruments, etc. 3. Changes to or permanently bypassing ESD/shutdown components and logic. ❑ DI 4. Changes to or permanently bypassing process control components and logic. ❑ 5. Installation,changes,or alterations to the eq,instrumentation,connectivity,layout,normal ❑ operating limits,calibration procedures,etc.,on a sales gas or condensate metering system. If yes,review 20AAC25.228 for requirements and obtain AOGCC approval. 6. Any Welding Involving: ❑ p 6.1 Installation of any hydrocarbon tank or pressure vessel and pressurized piping with the exception of water and air less than 150 psig design pressure. (No equipment in hydrocarbon service shall be installed without the approved MOC 6.2 Repair, Modification, or like-in-kind replacements to any hydrocarbon tank, pressure vessel or any regulated piping requires an approved MOC 6.3 Attachments (minor or otherwise, temporary or permanent) to major structural members,- deck and jacket legs, deck truss and jacket braces, deck girders spanning between deck legs, or any steel component greater than 1 '/a" in thickness. • • MOC SCREENING FORM (optional) - cont'd FACILITY MOC NAME MOC No. Swanson River Unit 21-27 Annular Flow Modification 7. Structural Modifications/Additions: o 7.1 More than 3 tons additional load (structure plus subsequent live loads) OR 7.2 More than 20 ft to the deck or walkway area. (In the event that work does not require MOC as-built drawings shall be submitted to Drafting Coordinator for updates) 7.3 Repair, modification or installation or a critical structural member. This should address any welding to a lifting device,trolley beam,personnel walkway supports,etc.) 8. Electrical Systems: 0 8.1 Changes and/or additions to the power generation and distribution system (switchgear, transformers, motor control centers). 8.2 Changes to the control logic. 8.3 Addition of equipment exceeding 75 kW power consumption. g. Any additions, Relocations, Modifications or Removal of the Following Equipment: 9.1 PSV's, safety equipment and systems (fire water deluge, fire detection, etc.) such as those included on Safety Equipment Layout and Escape Route drawings for the facility. 9.2 Equipment appearing on the P&ID's or plot plans. 9.3 Any electrical equipment permanently installed in an electrical hazardous area. 9.4 Any potential ignition source permanently installed in an electrical hazardous area. 9.5 Equipment exhausting or discharging hydrocarbons or other hazardous materials. 9.6 Maintenance activity that results in a change other than "in-kind" replacement 9.7 Mothballing, decommissioning, and abandonment. 10. Layout changes in enclosed areas (buildings, workshops, etc.) affecting points of ingress/egress, evacuation routes or electrical hazardous area classification 11. Changes to Process Fluids Including: o 11.1 Hydrocarbon and utility streams 11.2 Heat transfer fluids 11.3 Lubrication and seal oils 11.4 Fuels for process equipment and prime movers 12. Any Modification, Structurally, Procedurally or Otherwise that has the ❑ Potential Impact Helicopter Operations,such as; 12.1 Addition of an obstacle(s) to the helicopter approach/departure flight path; this includes both physical structures as well as exhaust gas and flare booms. 12.2 A layout change that would affect the way personnel embark/ disembark to/from the helicopter. 12.3 Any modification to the size or shape of the helideck. 12.4 Addition of lighting that may interfere with helicopter operations. • • MOC SCREENING FORM (Optional)cont'd FACILITY MOC NAME MOC NO. Swanson River Unit 21-27 Annular Flow Modification 13. Changes to the status of a well(i.e.),does work involve abandoning, plugging,or suspending a well? If yes, review 20AAC25.105 through 20AAC25.172. ❑ Completed by Date • • MOC REGULATORY SCREENING FORM (required) FACILITY: I MOC NAME MOC NO. Swanson River 21-27 Annular Flow Media Item Question? YES NO N/A 1. Does the project impact air,water,waste,land or fuel? O © E 2. Does the project involve use of fresh water? 1_1 L�L ga 3. Does the project involve moving land or use of waterways other O © O W than use of work boats in Cook Inlet? z 4. Is the project off Hilcorp's leased land? O © El 5. Have you discussed this project previously with someone in the O © CI Environmental Department? If yes,who?I I 6. Are you adding any temporary emission units? O O 7. Are you permanently removing any existing emission units? O O El 8. Will the design of any fuel burning equipment be modified(e.g., fuel system,firing controls,compression ratio, burner size or O O ol configuration? 9. Will the exhaust system,stack,or pollution control equipment for O O Ei any existing emission unit be modified? 10. Does the project involve changes to the method of operation that could result in increased usage of existing emission units or cc a throughout(e.g.,debottlenecking or removing a capacity limitation, O O lo changes in piping configuration, changes in control system configurations,changes in procedures)? 11. Does the project involve release, burning,or escape other than normal or incidental deminimus volumes of gas?If yes, review O O 20AAC25.235 for requirements and submit Form 10-422 to AOGCC as required. 12. Will the fuel type,source blending or quality change? O O 13. Will we reduce air emissions through reduced fuel usage, O O improved efficiency,pollution prevention,or pollution control? 14. Will the project effect discharges into Cook Inlet(including but not O O limited to rerouting discharge piping,commingling streams,etc.)? 15. Does project involve sending waste to an onshore facility based O O El I production wastewater treatment system? 15A Have the facility personnel been notified of the proposed O O El y commingling of fluids? W 15B Has an evaluation been conducted to determine if the fluids may O O a cause an upset to the treatment system? Z 16. Does the project involve bypassing any portion of a treatment system? O O 17. Are chemical treatment,usage, application,concentration, or O O procedures being modified? 18. Does the project involve changes to the piping or tanks of the O O wastewater system? y cI 19. Is Drilling performing required monitoring of drilling or work over O O W Z discharges?If yes,who is responsible for monitoring? zJ c 19A If Drilling is not monitoring drilling or work over discharges,has the O O IN project Foreman been informed of the discharge requirements? • 0 MOC REGULATORY SCREENING FORM (required) cont'd FACILITY: MOC NAME MOC NO. Media Item Question? YES NO N/A 20. Does the project involve sending E&P waste off the facility in containers? Q n 21. Does the project involve sandblasting? n Q lio 22. Does the project involve use of new chemicals at this facility?If yes,has 0 0 nii w the purchase been officially approved? i- 23. Are chemical treatment,usage application,concentration,or procedures 0 I I 3 being modified? 24. Does the project impact waste handling procedures?(Are you changing Q Q Di the way you handle waste?) 25. Does the project involve underground disposal of waste?If yes,review a o MI 20AAC25.252 for requirements. 26. Is the project located outside of a containment area? U U 27. Are liners being used in secondary containment for tanks and drums? U [-i H_ 27A If yes,are you logging daily inspection of the secondary containment? co 28. Are employees and contractors aware of spill notification and report d procedures? F. co 29. Are safeguards in place for prevention of spills(e.g.,shutoff systems, © a 0 overflow alarms,etc.)? 30. Will any liner associated with an in-service tank>10,000 gallons be n Q DI rendered inoperative for more than one 12 hour shift? Enter comments here.Please identify the item number for which you are commenting on: Completed By: Date: . . -.. 0 i-, • ............ .................. .......:........ ..... .... ,........ - . . ... . • . . ......... -. ..... ...„......„..... .._........ .. -. ..... I 1.: ( ! i I . 1. \No R31 ,,,, R/Att; l• ' •'•'••- e-- ........ ..,_. ..... 1 0 i 0 ' [• . 1 I li. OA. j ,...- ■ GiO •.... 4. iw .., ..:. ......_..... . . 4 V )* . . ::alli. . ' i.'404.'..i'..':.:':' ' tf '••- - • I • ......... .. I ._.....•..:. . . . . . . .. ,_ _ .,•,...-.. • • - el ••• .. • - ••.-••• . . . . . 1 1450_1 .41..CS4- A. - • - - AI,A,1504--•I ,,. • a _ ,Not-61-;b.-. ;.: • r • „..,... ... . .. . .... milgosminium • .. . . - : .. : • 1 • _ ..------ . . • .:. -.,.,:••, . . env. 1 . .. ..,.... •- : . .... . I • - - —• - • , . . • .., .••• . • , . , .. • : • .•." . , ..... . 0 . . I la I 160/11 0 111 . : 4 , ..p.4' .. • - ... •,.-. •,• • ....",::,: . ... ... . . ‘. . .• • ,, .. ... . (xi ,21-27 AimAfit Fiaco A3-1 , i• 1 [. 6 ctsAe ah4AA.Ve- 1 i 1 2) <tit CiV VALue" I 2),ftf,,,,P.A4. Git-s. L.Fr fit-A7 . It luFrof 1 I i ... I . e -,,,9• to-'''' 1 1 1 496t)./A94 i . . • 1 • . .-.. I i I - : , . 1 I 1 i 1 !.! • pr 0X010 ( � Swanson River Unit Well SRU 21-27 ACTUAL SCHEMATIC Wel l 10 Cometion Ililcarp Alaska,LLC ,4,,,....44.t F` ) �_ API: 50-133-10155-00 RKB=19' CASING DETAIL GL=184' 1 WT rade Con Btm atj- ' °2 20" - - - 40' 11-3/4" 47 J-55 8RD 11 Surface 2,029' 20'@40, 29 P-110 BTC 6.184 Surface 160' 26 N-80 BTC 6.276 160' 1091' 23 N-80 BTC 6.366 1091' 4783' 7" 26 N-80 BTC 6.276 4783' 6583' 29 P-110 BTC 6.184 6583' 8398' 4 29 P-110 8RD 6.184 8398' 11,142' 11-3Ir'e2,029' TUBING DETAIL 3-1/2" I 9.3 I L-80 I EUE 8RD I 2.992 I Surface 9,764' JEWELRY DETAIL. ?D 1 19' 2.992" 6.184" Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 3.500" X0,IBT Pin x EUE 8RD Pin 3 7,518' 2.992" 5.313" GL SF0-1 Mandrel,Dummy Valve 3 4 9,690' 2.992" 5.313" GL SF0-1 Mandrel,Dummy Valve h 5 9,764' - 4.000" Top of ESP,Discharge Head a6 9,968' - 5.520" Base of ESP,456 series Motors/400 series Pumps 7 10,007' 2.992" 3.500" Jet Cut Tubing,3-1/2" 8 10,016' 2.813" 5.750" Tripoint T-2 On/Off Tool 4 5 9 10,017' 3.000" 5.875" Tripoint AS1-X packer 10 10,031' 2.660" 3.900" XN Nipple 11 10,032' 3.000" 4.125" WL Entry Guide 1 Cable/Clamp/Band Detail �-ti 9,901'-9,968' - 8 ea 4560 Cannon Clamps(Across Motors Only) 7 9,763'-9,901' - 18 ea 4010 Cannon Clamps(Across Pumps/Gas Handler) 9,733'-9,763' - 9 ea%"SS bands(all on lstjoint above discharge head) 8 0'-9,733' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) 1 0'-9,781' - 1 ea Reda#1/#2 Flat ESP Cable(Splice depths at approx.35',5,000',and 9,781') kilt n 4 9 9,781'-9,933' - 1 ea MLE Flat Cable(Splice depth at approx..10,381') 10 r- 0'-9,744' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) XN 9,744'-9,968' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) 11 r 1 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Not TOP tagged @ =G G 10,633' 10,653 10,633' 10,653' 6 1/31/13 Open 2-1/8" 10,768' 9/22/12 - 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD _H-1 H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open =L- =H-2/H3 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" =H-4Mb H2/H3 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3-3/8" 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open 15ft completion - competion left in H4/H5 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Open bottom of well, unknown depth _ - T'@ 11,142' A .� �• - 7"Cement Bond Log TD=11,142' PBTD=11,000' 10,195'-10,280' Good 10,365'-10,432' - Fair Directional Data: 10,575'-10,604' - Good max hole angle=2.25°at 2035' MD 10,675'-10,710' - Fair uownhole Revised:08/30/13 Updated by STP 10/08/13 • Schwartz, Guy L (DOA) From: Stan Porhola <sporhola @hilcorp.com> Sent: Friday, November 01, 2013 10:12 AM To: Schwartz, Guy L(DOA) Cc: Regg,James B(DOA) Subject: RE: Request Approval for Annular Flow(SRU 21-27 PTD 161-010) Guy, We will be submitting a formal 10-403 sundry today that should include all the information requested. Let me know if the submittal has all the information that you need. Stan From: Schwartz, Guy L(DOA) [mailto:quy.schwartz @alaska.gov] Sent:Tuesday, October 22, 2013 9:33 AM To: Stan Porhola Cc: Regg,James B(DOA) Subject: RE: Request Approval for Annular Flow(SRU 21-27 PTD 161-010) Stan, The Commission would like to see a formal sundry application to approve annular flow in this well. Your supporting argument below is a great start but we would like to see addition documentation on the piping, IA SSV settings( is original SSV operational or locked out), and proof that the MOC (management of change) process was followed according to Hilltop's internal policy. Additionally, 20 AAC 25.265(e) requires capability to shut down artificial lift to the well; please describe how that will be accomplished (e.g., LPP/HPP tied to gas lift pump or shut down valve at gas lift manifold that isolates SRU 21-27. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Stan Porhola [mqilto:sporhola�ci hilcorp.com] Sent: Monday, October 21, 2013 3:36 PM To: Schwartz, Guy L(DOA) Subject: Request Approval for Annular Flow(SRU 21-27 PTD 161-010) Guy, We are requesting approval for annular flow of the SRU 21-27 well(PTD 161-010). A sundry was submitted to replace this ESP with a gaslift completion (sundry 313-548,current schematic attached), but we are currently waiting on completion equipment. 1 This well has a failed ESP that will not pump(appears to be a solids/scale issue that has locked up the pump).These solids are blocking the flow of fluids thru the ESP intake,preventing production up the tubing. In the interim,we have the ability to flow the well up the annulus using gaslift valves w/reverse check valves and placing an SSV on the annulus connection into the flowline.The casing was tested to 2,500 psi for 30 minutes on 9/24/2012. We are requesting to flow the well up the annulus for a period up to 6 weeks. Regards, g , Stan Porhola Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC 'porhola(P>hilcOr_p.CQrn Office: (9 07) 777-8412 Nlobile: (907) 331-8228 2 . up • �w\,,,��,,-t. THE STATE Alaska Oil and Gas �s - � ®fl 1 1 1VJ �.1 1 Ci nservation Commission k. GOVERNOR SEAN PARNELL rh 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS � Main: 907.279.1433 Fax: 907.276.7542 Stan Porhola SCANNED i,.�; 2 , ', Operations Manager 1 64 -:_____________--°/ Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 21-27 Sundry Number: 313-548 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, t/( ----- (M Cathy P.V erster Chair, Commissioner DATED this L day of October, 2013. Encl. ■ • •• STATE OF ALASKA • itikto5R IV OCT 1 4 2U13 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing 0 Time Extern ion❑ Operations Shutdowl❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ [SP-f e, 44 9Otheerr''12-- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number .1.-CA P,S '2 f T AM Hilcorp Alaska,LLC Exploratory ❑ Development la - 161-010 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. 50-133-10155-00 Anchorage,Alaska 99503 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B ' Swanson River Unit(SRU)21-27 - Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 ' Swanson River Field/Hemlock Oil ° 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,142' 11,142' ' 10,781' 10,781' N/A 10,007'(cut tubing) Casing Length Size MD ND Burst Collapse Structural Conductor 40' 20" 40' 40' Surface 2,029' 11-3/4" 2,029' 2,02g 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142 6,340 psi 3,830 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,764 Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): Tripoint AS1-X;N/A 10,017'MD&ND;N/A 12.Attachments: Description Summary of Proposal al 13.Well Class after proposed work: Detailed Operations Program f BOP Sketch F✓/ Exploratory [1 Stratigraphi{1 Development n Service 11 14.Estimated Date for 15.Well Status after propsed work: 10/19/13 Commencing Operations: Oil el - Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email soorholaOhilcorD.com Printed Name Stan Po,,ola, Title Operations Engineer t l Signature /` w' /t"- Phone 907-777-8412 Date L /, I( / / 3 COMMISSION USE ONLY !!! Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3V7-3— 144% Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS OCT 2. 5 20 Other: J� 30 OD p5-% $o / Cis Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: J o - 'y8 Cf APPROVED BY �� /� Approved by: COMMISSIONER THE COMMISSION Date: ., /6•is-:/3 Y"-t Submit Form and 1' k l� Form 10-403(Revised 10/2012) ApFo a li o li o 12 months fr the date of approval. Atfchments in Duplicate /;v',X S • Well Prognosis Well: SRU 21-27 Hilcory Alaska,LL, Date:10/09/2013 Well Name: SRU 21-27 API Number: 50-133-10155-00 Current Status: ESP Oil Well Leg: N/A Estimated Start Date: October 19th, 2013 Rig: Moncla#405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 161-010 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,500 psi @ 10,748' TVD (Static pressure Aug 2013 based on ESP sensors mid perf of 10,748' MD) Maximum Expected BHP: —2,500 psi @ 10,748' TVD (Static pressure Aug 2013 based on ESP sensors mid perf of 10,748' MD) Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 4,255 ft. ND. Brief Well Summary This well was drilled and completed as an oil well in Hemlock benches H-1 thru H-5 in 1961.A workover performed in 1962 pulled the existing completion, made a cleanout run, and ran a new completion.A workover in 2009 attempted to pull the completion but left some of the original 1962 completion in the well.A workover performed in 2012 removed the new tubing and packer, was able to recover the older existing packer, reperforated selected zones in the Hemlock and ran a new gaslift completion.The Tyonek G zone was perforated thru-tubing in 2013.An ESP was installed in August 2013.While producing,the ESP experienced ' issues with solids/scale that led to daily shutdowns of the ESP and an increased rate of gas also affected ESP performance.The planned workover will pull the existing ESP and convert the well back to a gaslift completion . and install a capstring after moving off the workover rig. Notes Regarding Wellbore Condition • Current well status is ESP oil producer. . Work-Over Rig Procedure 1. MIRU Moncla 405 pulling unit. 2. Set BPV in tubing hanger, ND tree, NU 7-1/16" BOPE and test to 250psi low/3,000psi high,annular to 250psi low/1,500psi high (hold each valve and test for 5-min). Record accumulator pre-charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. 3. Release test pressure, pull BPV and install handling sub in hanger. w�' /Z�✓o p�: 4. Back out tbg hanger hold down pins and pick up on hanger. Cs.' K d 5. RU to pull tubing hanger and and SOOH with 3-1/2" production tubing and ESP from 9,968'. / 4070- a. Full joint of 3-1/2" 8RD(Pin Up) located below hanger. b. Inspect cable for damage. • Well Prognosis Well: SRU 21-27 Hilcorp Alaska,LL) Date:10/09/2013 c. Inspect motors, seals,and pumps for damage. d. Send motors and protectors to ESP shop for redress. 6. RIH w/overshot and engage tubing stub at 10,007'. 7. POOH w/cut tubing and packer(or work to bottom if unable to move uphole). 8. RIH and set mechanical packer at+/- 10,500' MD. a. Pre-load lower X-profile with RHCP plug. b. Space out Gaslift Mandrels per Gaslift Design. c. Run live valves in Gaslift Mandrels. /1'6-'4-- .3t' h� -� 9. Drop RHCP prong. Circulate 3%KCI and pressure up to 1,500 psi to test casing. 10. Test tubing to 1,500 psi. 11. Set BPV, ND BOPS, NU Tree,test tree to 3,000 psi. a. Note: Rated pressure of BIW penetrator(wellhead to cable connection) is 3,000 psi. 12. RDMO workover rig and equipment. 13. Rig up slickline. PT lubricator to 3,000 psi Hi 250 Low. 14. RIH and pull RHCP prong and plug. '- 15. Turn well over to production. Capstring procedure: 1. MIRU Cap String Truck, PT lubricator to 3,000 psi Hi 250 Low. 2. PU 3/8" capillary string. RIH and set at+/- 10,510'. 3. Set spool of remaining line near well. 4. Rig down Cap String Truck. 5. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic • i Swanson River Unit Well SRU 21-27 ACTUAL SCHEMATIC Swanson PTD: 61-010 Hilcorp Alaska,LLC API: 50-133-10155-00 RKB=1g CASING DETAIL GL=184' -‘ Size WT Grade Conn ID Top Btm 1 _, 20" 40' 2 ps Ali 11-3/4" 47 1-55 8RD 11 Surface 2,029' 20"@40' «" 29 P-110 BTC 6.184 Surface 160' @ 26 N-80 BTC 6.276 160' 1091' 7„ 23 N-80 BTC 6.366 1091' 4783' 26 N-80 BTC 6.276 4783' 6583' 29 P 110 BTC 6.184 6583' 8398' € r 29 P-110 8RD 6.184 8398' 11,142' 114/4"@2,029 i 2 1 0 TUBING DETAIL 51 I j3-1/2" 9.3 L-80 I EUE 8RD I 2.992 I Surface I 9,764' CAP v0 i � le. JEWELRY DETAIL No Depth ID OD Item 1 19' 2.992" 6.184" Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 3.500" X0,IBT Pin x EUE 8RD Pin 3 7,518' 2.992" 5.313" GL SFO-1 Mandrel,Dummy Valve iliZX 3 4 9,690' 2.992" 5.313" GL SFO-1 Mandrel,Dummy Valve 5 9,764' - 4.000" Top of ESP,Discharge Head 6 9,968' 5.520" Base of ESP,456 series Motors/400 series Pumps 7 10,007' 2.992" 3.500" Jet Cut Tubing,3-1/2" 8 10,016' 2.813" 5.750" Tripoint T-2 On/Off Tool OEM 4 9 10,017' 3.000" 5.875" Tripoint AS1-X packer 10 10,031' 2.660" 3.900" XN Nipple ` 11 10,032' 3.000" 4.125" WL Entry Guide 5 Cable/Clamp/Band Detail 6 9,901'-9,968' - 8 ea 4560 Cannon Clamps(Across Motors Only) 9,763'-9,901' - 18 ea 4010 Cannon Clamps(Across Pumps/Gas Handler) 11 7 9,733'-9,763' - 9 ea%"SS bands(all on 1st joint above discharge head) ', 8 0'-9,733' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) 1 I t t , 0'-9,781' - 1 ea Reda#1/#2 Flat ESP Cable(Splice depths at approx.35',5,000',and 9,781') 9 9,781'-9,933' - 1 ea MLE Flat Cable(Splice depth at approx.. 10,381') 10 1s 0'-9,744' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) M9,744'-9,968' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) 11 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes TOFtagged@ _G G 10,633' , 10,653' 10,633' 10,653' 6 1/31/13 Open 2-1/8" 10,768'-9/22/12 10,672' - 10,673' 10,672' 10,673' 5 5/2/1961 SQZD H-1 H1 10,676' - 10,696'- 10,676' 10,696' 4 5/4/1961 Open =H-2/H3 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" : y .,` k< " H2/H3 10,708' , 10,768' . 10,708' 10,768' 6 9/23/2012 Open 3-3/8" r d; H-4/H-5 10,710' • 10,773' • 10,710' 10,773' 4 5/4/1961 Open 15ftofonginal completion left in H4/H5 10,778' ` 10,805' - 10,778' 10,805' 4 5/4/1961 Open ur cnnown depth �" i t � 11 , 7"Cement Bond Log 7"@11,a a ; ?.... 10,195'-10,280' - Good TD=11,142' PBTD=11,000' 10,365'-10,432' Fair Directional Data: 10,575'-10,604' - Good max hole angle=2.25°at 2035'MD 10,675'-10,710' - Fair Downhole Revised:08/30/13 Updated by STP 10/08/13 . n1 • • Swanson River Unit Well SRU 21-27 • PROPOSED SCHEMATIC PTPropose 16d010 Completion Hilcorp Alaska,LLC API: 50-133-10155-00 RKB=19' CASING DETAIL GL=184' ' Size WT Grade Conn ID Top Btm Al ' , L 20" - - - 40' 11-3/4" 47 J-55 8RD 11 Surface 2,029' 2°°@40' 29 P-110 BTC 6.184 Surface 160' 26 N-80 BTC 6.276 160' 1091' 23 N-80 BTC 6.366 1091' 4783' 7 26 N-80 BTC 6.276 4783' 6583' 29 P-110 BTC 6.184 6583' 8398' 4 29 P-110 8RD 6.184 8398' 11,142' 113/4"@2,029' TUBING DETAIL 1 1 3-1/2" 9.3 L-80 8RD EUE 2.992 Surface 10,545' 1 2 JEWELRY DETAIL No Depth ID OD Item 1 3,300' 2.992 5.313 GL SFO-1 Mandrel,Port 12 1 3 2 5,600' 2.992 5.313 GL SFO-1 Mandrel,Port 12 3 7,200' 2.992 5.313 GL SFO-1 Mandrel,Port 12 4 8,350' 2.992 5.313 GL SFO-1 Mandrel,Port 16 4 5 9,250' 2.992 5.313 GLSFO-1 Mandrel,Port 16 6 9,950' 2.992 5.313 GLSFO-1 Mandrel,Port 16 7 10,450' 2.992 5.313 GL SFO-1 Mandrel,Orifice 20 8 10,499' 2.813 5.750 Tripoint T-2 On/Off Tool 5 9 10,500' 3.000 5.875 Tripoint AS1-X packer 10 10,514' 2.813 3.900 X Nipple 11 10,545' 3.000 4.125 WL Entry Guide 1 6 PERFORATION DATA 1 7 Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes G 10,633' 10,653 10,633' 10,653' 6 1/31/13 Open 2-1/8" 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD 1 H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open 8 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" j 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3-3/8" 1 E-- ,,, H2/H3 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open s -=- H4/H5 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Open 10 x 11 / ` Capillary String Plan to install - 3/8" 2205 Stainless Steel TOF tagged @ -G Top Bottom 10,768'-9/22/12 MD 0' 10,510' V =H-1 TVD 0' 10,510' - =H-2/H-3 :-H-4/H-5 15 ft of original ' completion left in bottom of well 0 unknown depth r @11,14? 4. ", 7"Cement Bond Log 10,195'-10,280' - Good TD=11,142' PBTD=11,000' 10.365'- 10,432' - Fair Directional Data: 10,575'- 10,604' - Good max hole angle=2.25°at 2035'MD 10,675'- 10,710' - Fair Downhole Proposed Updated by STP 10/09/13 . . • •• , ll Swanson River 2013 Moncla Rig#405 Knight Oil Tools BOP • • I I I I I I I t l I I I i i t" iAI I I I I I I 2.57' Shaffer 7 1/16 5000 Ills lit 11111i tit IiI III 1_114 iil I[t ab 2 3/8-3 1/2 variable - CAMERON - 3.68' _.■ Ill. 1�� _ Blind 7 1/16 5000 Iwo, _ - ill ill iii ill ill NM' Choke and Kill valves are 2 1/16 10M i!1'1_!1'Ifl I I I 1.56' l 1Q:I !!g iiii' 7 1/16 5000 O . to „ * ! i ,„,'. ill_ .6,11.4iiwi III It1■ i Iii 11 STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS '° "u i' 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U • Other[J Performed: Alter Casing ❑ Pull Tubing 0 • Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory ❑ 161-010 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6-API Number: Anchorage,Alaska 99504 50-133-10155-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 ' Swanson River Unit(SRU)21-27 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil • 11.Present Well Condition Summary: Total Depth measured 11,142 feet Plugs measured N/A feet true vertical 11,142 feet Junk measured 10,768(fill) feet Effective Depth measured 10,768 feet Packer measured 10,017 feet true vertical 10,768 feet true vertical 10,017 feet Casing Length Size MD ND Burst Collapse Structural Conductor 40' 20" 40' 40' Surface 2,029' 11-3/4" 2,029' 2,029' 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached Schematic � iV ri v 1 9 °'r'r,3 r True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,968'MD 9,968'ND Packers and SSSV(type,measured and true vertical depth) Tripoint AS1-X 10,017'MD 10,017'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 95 3,404 501 1,150 380 Subsequent to operation: 90 812 654 157 165 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Q . Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-352 Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date G 3 3 loom.(3 RED S OCT 11 21.4i Form 10-404 Revised 10/2012 �%Iv(O�y�� Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 21-27 50-133-101255-00 161-010 8/23/13 8/30/13 Daily Operations: 08/23/2013- Friday MIRU SLU & RIH w/GR to 10,500' POOH. PU MU pulling tool &try to pull #7 gas lift valve. Tried several times, unsuccessful. RIH w/ new tool tried to pull #6 several times w/ no success. POOH. RIH w/new tool and pulled #6 valve. RDMO SLU. MIRU WOR & related Equipment &containment. MIRU WOR pump. Pump 70 bbls to kill well. Installed BPV in hanger. ND Production tree. NU BOPE. Had problems w/ BOPE. Had to get spacer spool from Knight oil tools. 08/24/2013-Saturday NU BOPE. MIRU accumulator& had leaks while doing function test. Had broken fittings on nitrogen bottles. Also had bad HCR valve. Waiting on Knight to bring new HCR valve and fix accumulator. Knight called and said they were bringing out new accumulator. RDMO accumulator. RU WOR floor&stairs, MU test sub. WO Knight. New accumulator showed u_p. MIRU accumulator&changed out fittings on BOPE. Had Knight install new HCR valve. Knight forgot to bring flange to hook up kill line hose. Had to go back to shop. Knight also couldn't find remote for accumulator. Found remote to accumulator at Williams Rig. Brought it to loc. MIRU remote &fuction test BOPE & remote. Waiting on flange from Knight. Knight showed up with flange. NU flange and start BOPE test. 08/25/2013-Sunday Perform BOP test as follows: annular to 250 psi low/2500 psi high; 2-3/8" x 3-1/2" VBR's, blind, HCR's, choke and kill manifold valves,TIW, IBOP, and Kelly valve to 250 psi low/3000 psi high. All components passed. Jim Regg,AOGCC waived witness 8/23/13 4:35. After BOPE test the 2 way check valve in hanger had pressure under it so had to get Cameron hand go to their yard to get lubricator. Bled backside down while waiting. Cameron hand showed up with lub. NU flange and &test lub and had leak on flange. Had to ND and fix ring grove. NU and test flange & lub. 3,000 psi. Good test. Pulled 2 way check. RDMO Cameron. Pump 90 bbls down tbg then down csg. Released packer. LD hanger and pup joints. While POOH w/ packer, packer was dragging 10-15K over PU weight. Contine to POOH with tubing and BHA. POOH, packer hung up. Could not go up or down. Pulled 25K over PU weight and sat 25K compression. Worked tubing multiple times with no change. RU TIW and Kelly hose. Pump 15 bbls down tubing at 4PM -Opsi. 08/26/2013- Monday POOH w/a total of 7 stands and 1 jt. SI secure well SDFN. Opened well. 30psi on tubing and casing. Released pressure to -0- . Continued to work tubing up and down. Made several attempts to release packer. Pulled from 120 to 165 over. Packer would not come free. It was decided by Hilcorp to pull up to 90%of the tensile strength of 3-1/2" 8RD tubing. Pulled up to 175K. Packer did not come free. RU power swivel. Made 30 turns to the right working torque every 5 rounds. Got 2-1/2 rounds back after 30 rounds. Put an additional 45 rounds to the right working torque up and down. Got 1 round back indicating that packer was spinning and no torque was being applied to the top of packer. Attempted to release from on-off tool. Made 8 rounds to the left working torque up and down. Could not get off the T-2 on-off tool. Released torque on power swivel and had no turns back to the right indicating that the packer was spinning. Called priority WLU. Waiting on unit. MIRU WLU and lub. Pump 100 bbls down tbg. 08/27/2013-Tuesday • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 21-27 50-133-101255-00 161-010 8/23/13 8/30/13 Daily Operations: PU MU 2-3/4" GR w/JB. RIH to 10,034'. POOH. LD GR &JB. PU MU 160 grain string shot. RIH to 10,017' fire shot and then pulled to see if PKR was free. PKR wasn't free. POOH. LD string shot. PU MU 2.65" tubing jet cutter. RIH to 10,007' pull 120K on tbg &fired cutter. Tbg weight fell to 75K. Picked up tbg 8' to insure tbg was cut. POOH w/WL tools. RDMO WLU. POOH SB tbg. PU MU Tripoint Pkr& RIH w/20 stands &set Pkr. Release from Pkr. POOH. Blew csg down to 0 psi. Fill csg and test Pkr to 1,500 psi for 10 min. Test good. ND BOPE. NU Cameron ESP spool. NU BOPE and test& chart all flanges to 3,000 psi for 10 min. Test Good. RIH w/20 stands and latch Pkr. Release Pkr and POOH w/tbg& Pkr. LD Pkr. MIRU SLU. Pump 100 bbls& RIH w/ LIB and tagged the stub of tbg on PKR @ 10,020' SLM. POOH. Had impression of stub sticking up. RDMO SLU SI secure well SDFN. 08/28/2013 -Wednesday Bleed down and pump 50 bbls water-well dead. LD 45 joints of 3-1/2" production tubing to make room. RD hydraulic catwalk. RU Schlumberger ESP equipment. RU spools, move and stage ESP components. Pump 150 bbls water and ensure well is dead. PU ESP motors and RIH, securing tri-flatpack encapsulated control lines w/clamps. Prepare to PU ESP pump section when Schlumberger employee let go of tail end of ESP flat cable going through sheave and cable bent after hitting sheave. LD sheave and cut damaged cable, splice with new cable. Pumping 20 bbls water every 2 hours. PU sheave and spliced flat cable. Begin picking up ESP pump sections and RIH . 08/29/2013-Thursday Continue MU and RIH w/ESP pump sections, shimming as necessary to get proper alignment. Pump 20 bbls water every 2 hours to ensure well is dead. Connect pressure control line to discharge sub/XO and test control lines and flat cable -tested good. PU 2 joints of 3-1/2" 9.3# L-80 EUE, RIH and install GLM w/dummy valves. RIH w/ ESP assembly on 68 joints of 3-1/2" 9.3# L-80 EUE and install GLM w/dummy valves. Continue RIH w/ ESP assembly on 3-1/2" 9.3# L-80 EUE production tubing. Strap&tally tubing and pump 20 bbls water every 40 joints to ensure well is dead. Noticed pressure bleeding off when testing control lines @ 6,600'. Troubleshoot and suspect air in lines or check valves on control lines leaking. Decision to continue RIH. Continue RIH w/ESP assembly on 3-1/2" 9.3# L-80 EUE production tubing. Strap &tally tubing and pump 20 bbls water every 40 joints to ensure well is dead. 08/30/2013- Friday Swap spools and perform splice on ESP flat cable @ "9,100'. Check continuity-good. Continue RIH w/ ESP on 3-1/2" 9.3# L- 80 EUE production tubing. PU 27 joints, 5' pup joint, and single joint. MU tubing hanger. Install BIW penetrator and make mark, cut flat cable and splice. Check continuity-good. RD extra Schlumberger equipment. RIH and install BIW penetrator and secure. Connect chemical injection lines and test-tested good. Land tubing and hang off. Secure lockdown screws. Bottom of ESP: 9,968' MD. RKB Intake: 9,884'. GLM's: 9,690' &7,518'. LD landing joint and install BPV. RD choke and kill manifold lines. RD rig floor. ND BOP, install bonnet seal and NU wellhead. Test wellhead to 3,000 psi -good test. Pull BPV. RD and prepare to mob to SCU 32-8. • Swanson River Unit H 0 Well SRU 21-27 ACTUAL SCHEMATIC Completion 161010an:08/30/2013 PTD Hilcora Alaska,LLC API: 50-133-10155-00 RKB=19' CASING DETAIL GL=184' Size WT Grade Conn ID Top Btm 2 20" - - - 40' .4 11-3/4" 47 J-55 8RD 11 Surface 2,029' 20"@4' 29 P-110 BTC 6.184 Surface 160' w �! 26 N-80 BTC 6.276 160' 1091' 7„ 23 N-80 BTC 6.366 1091' 4783' t l 26 N-80 BTC 6.276 4783' 6583' 29 P-110 BTC 6.184 6583' 8398' 1' 29 P-110 8RD 6.184 8398' 11,142' 11-3/4"@2,029' TUBING DETAIL 3-1/2" 9.3 L-80 I EUE 8RD I 2.992 I Surface I 9,968' JEWELRY DETAIL No Depth ID OD Item 1 19' 2.992" 6.184" Tubing Hanger IBT Box x IBT Box 2 20' 2.992" 3.500" X0,IBT Pin x EUE 8RD Pin 3 7,518' 2.992" 5.313" GL SFO-1 Mandrel,Dummy Valve If i' 3 4 9,690' 2.992" 5.313" GL SFO-1 Mandrel,Dummy Valve 5 9,968' - 5.520" ESP,456 series Motors/400 series Pumps 6 10,007' 2.992" 3.500" Jet Cut Tubing,3-1/2" 7 10,016' 2.813" 5.750" Tripoint T-2 On/Off Tool 8 10,017' 3.000" 5.875" Tripoint AS1-X packer um p 4 9 10,031' 2.660" 3.900" XN Nipple 10 10,032' 3.000" 4.125" WL Entry Guide Cable/Clamp/Band Detail 9,901'-10,600' - 8 ea 4560 Cannon Clamps(Across Motors Only) 5 9,763'-9,901' - 18 ea 4010 Cannon Clamps(Across Pumps/Gas Handler) 6 9,733'-9,763' - 9 ea%"SS bands(all on 1st joint above discharge head) I 0'l 7 -9,733' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) lit 0'-9,781' - 1 ea Reda#2 Flat ESP Cable(Splice depths at approx..35',4,000',and 9,781') I•!AR t " 9,781'-9,933' - 1 ea MLE Flat Cable(Splice depth at approx.. 10,381') - :* 8 0'-9,744' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) 9 ' ' 9,744'-9,968' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) imi 10 PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes G 10,633' 10,653 10,633' 10,653' 6 1/31/13 Open 2-1/8" -G 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD 768 9d@ 10,768'--9/22/12 H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open 10 _ =H-1 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" =H-2/H 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3-3/8" H-2/H-3 H2/H3 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open " ,r),' H-4/H-5 H4/H5 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Open 15 ft of original completion left in bottom of well, rit" p *erg ., unknown depth y t - A "ir ."' ,r 7"Cement Bond Log x @11,142' ...4"4*' ;a . 10,195'-10,280' - Good TD=11,142' PBTD=11,000' 10,365'-10,432' - Fair Directional Data: 10,575'-10,604' - Good max hole angle=2.25°at 2035'MD 10,675'-10,710' - Fair Downhole Revised:08/30/13 Updated by STP 09/27/13 Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Tuesday,August 20, 2013 8:33 AM To: 'Stan Porhola' Subject: RE:Change of Workover Rig for SRU 21-27 ESP Conversion (Sundry#313-352) PTD O 161-010 fr Stan, Thanks for heads up... no other notification is needed. Guy Schwartz SCANNED , t 1 ^' Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Stan Porhola [mailto:spor hold hilcor .ccfp] Sent: Monday, August 19, 2013 6:29 PM To: Schwartz, Guy L(DOA) Subject: Change of Workover Rig for SRU 21-27 ESP Conversion (Sundry#313-352) Guy, We are currently planning to change workover rigs for the SRU 21-27 ESP Conversion (Sundry#313-352). We will change from the Williams#405 to the Cloverleaf#4(currently active for Hilcorp in the Kenai Gas Field), using the same 7" BOPE as proposed in the original sundry. Let me know if you need any additional information. Regards, Stan Porhola Operations Engineer North Kenai Asset Team Hilcorp Alaska,LLC sporho1g(,Mrnic c�r_f�_corl Office. (9P7) 777-8-112 1 THE STATE GOVERNOR SEAN PARNELL SaHNED N0%' 0 4 2, 13 Stan Porhola Operations Engineer ^ O r O Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 21-27 Sundry Number: 313-352 Dear Mr. Porhola: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this day of July, 2013. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS nn AAr'M 74n 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well ❑ Change Approve" Prograrn ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing Q Time Extension ❑ Operations Shutdovn ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing[—] Other: Convert to ESP 0 2. Operator Name: 4. Current Well Class: 5_ Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ElDevelopment ❑✓ ' Stratigraphic ❑ Service ❑ 161-010 ` 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number. Anchorage, Alaska 99503 50-13310155-00 ' 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123A ❑ ❑✓ Swanson River Unit (SRU) 21-27 .� Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River Field / Hemlock Oil ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 1 Junk (measured): 11,142' 11,142' 10,781' 10,781' N/A 10,781' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 40' MY Surface 2,029' 11-3/4" 2,029' 2,029 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,147 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.311! L-80 10,501 Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Tripoint AS1-X; N/A 10,486' MD & TVD; WA 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphif] Development n Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 07/18/13 Oil ❑✓ • Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email r . Printed Name Stan Porho_la Title Operations Engineer Signature L— (7Lti Phone 907-777-8412 Date �i fj3 /13 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Q `� J Plug Integrity ❑ BOP Test 64/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: j� 36/w /VSL'1 DD! --?;� �— �la� `f�t.s � /`[. u�/ '✓0�-vX S -f -'vb ; �: Tom' (��'oaCu-tel RBDMS JUL 10 20 Spacing Exception q ' red? Yes ❑ No Subsequent Form Required: APPROVED BY THOMMISSION E C -7 Date: ` Approved by: COMMIS O 11 `% R 1V 1'v ?•d 13 Submit Form and \/ ;� Form 10-403 (Revised 10/2012) Approved application is valid for 12 months from t e a of ap oval. Attachments in Duplicate / 0 Hileorp Alaska, LL, Well Prognosis Well: SRU 21-27 Date:7/03/2013 Well Name: SRU 21-27 API Number: 50-133-10155-00 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: JUly 181h, 2013 Rig: Williams #405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 161-010 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP Max. Allowable Surface Pressure Brief Well Summary 2,150 psi @ 10,748' TVD 2,150 psi @ 10,748' TVD 0 psi (Static survey May 2012 mid pert of 10,748' MD) (Static survey May 2012 mid pert of 10,748' MD) (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 2,624 ft. TVD. This well was drilled and completed as an oil well in Hemlock benches H-1 thru H-5 in 1961. A workover performed in 1962 pulled the existing completion, made a cleanout run, and ran a new completion. A workover in 2009 attempted to pull the completion but left some of the original 1962 completion in the well. A workover performed in 2012 removed the new tubing and packer, was able to recover the older existing packer, reperforated selected zones in the Hemlock and ran a new gaslift completion. The Tyonek G zone was perforated thru-tubing in 2013. The planned workover will pull the existing completion and convert the well from a GL completion to ESP completion. Notes Regarding Wellbore Condition • Current well status is gas lifted oil producer. ' Work -Over Rig Procedure 1. MIRU Williams 405 pulling unit. >>* Lt✓'� G � 4,✓o�-rY 2. Install back pressure valve in tbg hanger. Note: If hanger profile is not test worthy, call out slick line with tubing stop/plug and set at 500'. 3. Set BPV in tubing hanger, ND tree, NU 7-1/16" BOPE and test to 250psi low/3,OOOpsi high, annular to 250psi low/1,500psi high (hold each valve and test for 10 -min). Record accumulator pre -charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Notify BLM 48 hrs in advance of BOP test. c. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and ROPE. 4. Release test pressure, pull tubing stop or BPV and install handling sub in hanger. 5. Back out tbg hanger hold down pins and pick up on hanger. Well Prognosis Well: SRU 21-27 HilcorP Alaska, LL Date: 7/03/2013 6. RU to pull tubing hanger and unseat Arrowset ASI-X packer at 10,486' (right-hand release) and SOOH with 3-1/2" production tubing down to 10,501'. Jar tubing hanger and packer loose if necessary. a. If unable to unseat packer, attempt to release from the On/Off Tool at 10,485'. b. If unable to unseat packer or On/Off Tool, RIH with E -line and use radial cutting torch to cut 3-1/2" tubing at +/- 10,470'. c. SOOH with tubing and RIH with overshot and jars and pull AS1-X packer. 7. PU 7" retrievable bridge plug and set at 500' using existing 3-1/2" 8rd EUE L-80 tubing, POOH. 8. Test plug to 1,500 psi. 9. ND ROPE. 10. NU new tubing head attachment spool. Test tubing head attachment spool to 5,000 psi. 11. NU BOPE and shell test to 250 psi low/3,000 psi high (test all flanges that were separated). 12. Unseat retrievable bridge plug. Monitor well for 15 mins. 13. POOH and LD retrievable bridge plug. 14. RIH with ESP with existing 3-1/2" 8rd EUE L-80 tubing. Set ESP at +/-10,600'. Land tubing hanger. 15. Set BPV, ND BOPS, NU Tree, test tree to 3,000 psi. a. Note: Rated pressure of BIW penetrator (wellhead to cable connection) is 3,000 psi. 16. RDMO workover rig and equipment. 17. Turn well over to production. 18. Notify AOGCC to conduct a no flow test on the well after it has flowed for 5 days at a stable production. Attachments: 1. As -built Schematic 2. As -built Wellhead 3. Proposed Schematic 4. Proposed Wellhead 5. BOP Schematic Hilcorp Alaska, LLC 20" 113H TOF 10,7 15 car bot unI T' @ RKB =19' GL =184' • ACTUAL SCHEMATIC • Swanson River Unit Well SRU 21-27 Actual Completion: 09/24/2012 PTD: 161-010 API: 50-133-10155-00 CASING DETAIL Size WT Grade Conn ID Top Btm 20" - GLSFO-1 Mandrel, Port 12 2 5,606' 2.992 40' 11-3/4" 47 J-55 8RD 11 Surface 2,029' 8,337' 29 P-110 BTC 6.184 Surface 160' 5.313 26 N-80 BTC 6.276 160' 1091' 7 23 N-80 BTC 6.366 1091' 4783' 7 26 N-80 BTC 6.276 4783' 6583' Tripoint ASS -X packer 29 P-110 BTC 6.184 6583' 8398' 10,501' 29 P-110 8RD 6.184 8398' 11,142' TUBING DETAIL 3-1/2" 9.3 L-80 I 8RD EUE 1 2.992 1 Surface 10,501' JEWELRY DETAIL No Depth ID OD Item 1 3,305' 2.992 5.313 GLSFO-1 Mandrel, Port 12 2 5,606' 2.992 5.313 GL SFO -1 Mandrel, Port 12 3 7,181' 2.992 5.313 GL SFO -1 Mandrel, Port 12 4 8,337' 2.992 5.313 GL SFO -1 Mandrel, Port 16 5 9,237' 2.992 5.313 GL SFO -1 Mandrel, Port 16 6 1 9,951' 2.992 5.313 GL SFO -1 Mandrel, Port 16 7 10,443' 2.992 5.313 GL SFO -1 Mandrel, Orifice 20 8 10,485' 2.813 5.75 Tripoint T-2 On/Off Tool 9 10,486' 3 5.875 Tripoint ASS -X packer 10 10,500' 2.66 3.9 XN Nipple 11 10,501' 3 4.125 WL Entry Guide PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes G 10,633' 10,653 10,633' 10,653' 6 1/31/13 Open 2-1/8" 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3-3/8" H2/H3 10,710' 10,773' 1 10,710 10,773' 4 5/4/1961 Open H4/H5 10,778' 10,805' 1 10,778' 1 10,805' 4 5/4/1961 Open TD =11,142' PBTD =11,000' Directional Data: max hole angle = 2.250 at 2035' MD 7" Cement Bond Log 10,195'- 10,280' Good 10.365' - 10,432' Fair 10,575' - 10,604' Good 10,675' - 10,710' - Fair Downhole Updated: 09-24-12 Updated by STP 07-03-13 CURRENT WELLHEAD Swanson River SRU 21-27 11 3/4 X 7 X 2 7/8 BHTA, Bowen 3", 2 9/16 5M FE Valve swab, WKM-M 2 9/16 5M FE, HWO, AA Valve wing, WKM-M k 2 9/16 5M FE, HWO, AA p ` Qty 3 0 ( o) O �< Tee, stdd, 2 9/16 5M X 2 9/16 5M Adapter, Shaffer-AJO, 7 1/16 5M stdd X 2 9/16 5M, w/ 1-'/z control line exit 6'/4' seal pocket Tubing head, Shaffer T55 -1-I, 13 5/8 3M X 7 1/16 5M w/ 2- 2 1/16 5M SSO, 7" Type 1 secondary seal in head Casing head, Shaffer KD, 13 5/8 3M X 11 3/4 SOW, w/ 2- 2" LPO, 7" KD slips and packoff assy in head Swanson River SRU 21-27 02/09/2012 Tubing hanger, Shaffer T55- AJO, 7 X 2 7/8 IBT lift and 2 7/8 IBT-M susp, w/ 2'/" type H BPV profile, 3/8 control line • s Valve upper master, WKM-M 2 9/16 5M FE, HWO, AA Valve lower master, oWKM-M 2 9/16 5M FE, '* HWO, AA 0 Ground Level Valve, WKM-M , 2 1/16 5M FE, HWO, Qty 2 Valve, plug, Rockwell, 2" LPO, Hilcorp Alaska, LLC 20" � 11-31 TOF 10,7 15 Do( bol unl 7" C RKB = 19 GL=184' • • PROPOSED SCHEMATIC CASING DETAIL Swanson River Unit Well SRU 21-27 Proposed Completion PTD: 161-010 API: 50-133-10155-00 Size WT Grade Conn ID Top Btm 20" - G 10,633' 10,653 10,633' 40' 11-3/4" 47 J-55 8RD 11 Surface 2,029' 10,672' 29 P-110 BTC 6.184 Surface 160' 10,676' 26 N-80 BTC 6.276 160' 1091' 23 N-80 BTC 6.366 1091' 4783' 7„ 26 N-80 BTC 6.276 4783' 6583' 10,768' 29 P-110 BTC 6.184 6583' 8398' 10,773' 29 P-110 8RD 6.184 8398' 11,142' TUBING DETAIL 3-1/2" 9.3 L-80 I 8RD EUE 1 2.992 1 Surface 1 10,600' JEWELRY DETAIL No Depth ID OD Item 1 19' 2.992" 1 7.000" Tubing Hanger w/ IBT x 8rd EUE XO 2 10,600' - 4.560" ESP, 456 series Motors / 400 & 387 series Pumps PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF Date Condition Notes G 10,633' 10,653 10,633' 10,653' 6 1/31/13 Open 2-1/8" 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3-3/8" 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3-3/8" H2/H3 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open H4/H5 1 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Open TD =11,142' PBTD =11,000' Directional Data: max hole angle = 2.250 at 2035' MD 7" Cement Bond Log 10,19S'- 10,280' Good 10.365' - 10,432' Fair 10,575' - 10,604' Good 10,675' - 10,710' Fair Proposed Completion Updated by STP 07-03-13 Swanson River UPROPOSED WELLHEAD SRU 21-27 nt�� Iw>►._ r ( 07/02/2013 Swanson River SRU 21.27 11314X7X31/7 BHTA, Bowen, 3 1/8 5M FE X 3" Bowen top Valve, swab, WKM-M, 3 1/8 5M FE, HIM, DD trim Valve, Wing, WKM-M, 2 1/16 SM FE, HWO, DD trim 0 Valve, master, WKM-M, - �,. , r '1 Tubing head Attachment, Seaboard S-8, 7 1/16 5M FE 7 1/16 SM FE Tubing head, Shaffer T55 -LI, 13 5/8 3M X 7 1/16 5M w/ 2- 2 1/16 5M SSO, 7" Type 1 secondary seal in head Casing head, Shaffer KD, 13 5/8 3M X 11 3/4 SOW, w/ 2- 2" LPO, 7" KD slips and packoff assyin head 0 Tubing hanger, Seaboard - S -ESP, 7 X 3'/2 BTC lift and susp, w/ 2-'/4 control line exits, prepped for BIW Kwiklok penetrator F. Seaboard -ESP, Rotating Flange X Rotating Flange, I, BIW penetrator Valve. WKM-M . 2 1116 1 5M FE, MO. Oty 2 Valve, plug, Rockwell, 2" LPO, 5��00 � gyp, � Q 3 F. Seaboard -ESP, Rotating Flange X Rotating Flange, I, BIW penetrator Valve. WKM-M . 2 1116 1 5M FE, MO. Oty 2 Valve, plug, Rockwell, 2" LPO, Swanson River 2013 Williams Rig 405 Knight Oil Tools BOP Hilrnrp Alarku. LI.S. RECEIVED STATE OF ALASKA MAR 1 .q 2013 ALOIA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory ❑ - 161 -010 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 -- 50- 133 - 10155 -00 `°'0ta 7. Property Designation (Lease Number): 8. Well Name and Number: , FEDA028406 ' Swanson River Unit (SRU) 21 -27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,142 feet Plugs measured N/A feet true vertical 11,142 feet Junk measured 10,768 (fill) feet Effective Depth measured 10,768 feet Packer measured 10,486 feet true vertical 10,768 feet true vertical 10,486 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 40' 40' —.. Surface 2,029' 11 -3/4" 2,029' 2,029' 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached Schematic APR P R 1 9 203, True Vertical depth See Attached Schematic SCANNED Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# / L -80 10,501' MD 10,507' TVD Packers and SSSV (type, measured and true vertical depth) Tripoint AS1 -X 10,486' MD 10,4864ZVD• - "' N /A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 35 5 550 1,300 300 Subsequent to operation: 63 400 633 1,520 480 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Developments Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil r N,I Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Chad Helgeson Email chelgeson@hilcorD.com Printed Name Chad Helgeson Title Operations Manager Signature ( /'66y,/ Phone 907 - 777 -8405 Date 3I(/13 R RDMS MAR 12 41 Al 4/./1-/3 v .�1-i3 Form 10 -404 Revised 10/2012 Submit Original Only • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 21 -27 50- 133 - 101255 -00 161 -010 1/31/13 1/31/13 Daily Operations: 01/30/2013 - Wednesday No activity to report. 01/31/2013 - Thursday Mobe a -line to location. Spot equipment, rig up lubricator and pressure test to 250 psi low and 2500 psi high. TP - 1,150 psi and casing 1,300 psi. RIH with 2 -1/8" x 20' HC, 6 spf, 60 deg phase perf gun and tie into GR /CCL dated 9/21/12. Spot perf gun from 10,653' to 10,633' per Final Approved Perf Request Form dated 1/28/13. Fired gun and no pressure change. POOH and all shots fired. Rig down lubricator and cleaned up area. 02/01/2013 - Friday No activity to report. 02/02/2013 - Saturday No activity to report. 02/03/2013 - Sunday No activity to report. 02/04/2013 - Monday No activity to report. 02/25/2013 - Tuesday No activity to report. • • Swanson River Unit Well SRU 21-27 SCHEMATIC Last Completed: 09/24/12 PTD: 161 -010 HB.wrp AlaRka, I.LC API: 50- 133 - 10155 -00 RKB GL =184' CASING DETAIL Size WT Grade Conn ID Top Btm ` 20" 40' s ia 11 -3/4" 47 J -55 8RD 11 Surface 2,029' � if 29 P -110 BTC 6.184 Surface 160' .4, 26 N -80 BTC 6.276 160' 1091' i4 r., 7„ 23 N -80 BTC 6.366 1091' 4783' k 26 N -80 BTC 6.276 4783' 6583' 29 P -110 BTC 6.184 6583' 8398' d 29 P -110 8RD 6.184 8398' 11,142' 11314" @2,029' TUBING DETAIL OF i 1 i 1 3 -1/2" 9.3 1 L -80 1 8RD EUE 1 2.992 I Surface 10,501' Imo, P 2 I JEWELRY DETAIL No Depth ID OD Item i 3 1 3,305' 2.992 5.313 GL SFO -1 Mandrel, Port 12 MB 2 5,606' 2.992 5.313 GL SFO -1 Mandrel, Port 12 3 7,181' 2.992 5.313 GL SFO 1 Mandrel, Port 12 V 4 8,337' 2.992 5.313 GL SFO -1 Mandrel, Port 16 MD 1 4 "r' 5 9,237' 2.992 5.313 GL SFO -1 Mandrel, Port 16 6 9,951' 2.992 5.313 GLSFO 1 Mandrel, Port 16 7 10,443' 2.992 5.313 GL SFO 1 Mandrel, Orifice 20 8 10,485' 2.813 5.75 Tripoint T -2 On /Off Tool IIIII ,, 5 9 10,486' 3 5.875 Tripoint AS1 -X packer 10 10,500' 2.66 3.9 XN Nipple 11 10,501' 3 4.125 WL Entry Guide wit 6 PERFORATION DATA in P 7 Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) SPF a Condition Notes / G 10,633' 10,653 10,633' 10,653' 6 31/13 Open 2 -1/8" ✓ 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD 1 8 H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3 -3/8" 1 1 H2 /H3 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3 - 3/8" 9 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open at H4 /H5 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Open 10 ' . in 11 TOF tagged @ en 10,768' - 9/22/12 H -1 H-2/H-3 $.r f -r MH4/H - 5 15 ft of original 1 ` completion left in '�j ,t ' k bottom of well, ' 1 e' 1 unknown depth A 3 . y t r @ 11,142 A ?,k " , * : , 7" Cement Bond Log TD = 11,142' PBTD = 11,000' 10,195' - 10,280' - Good 10.365' - 10,432' - Fair Directional Data: 10,575' - 10,604' - Good max hole angle = 2.25° at 2035' MD 10,675' - 10,710' - Fair Updated by DMA 03 -11 -13 fib ; SAVED STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMI ON �.: „ ,: 2012 ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Repair Well ❑ Plug Perforations LJ Perforate Other ✓ CN -RC lower - Performed: Alter Casing ❑ Pull Tubing INI Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ new GLV Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ ,, 161 -010 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 i 50- 133 - 10155 -00 00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 21 -27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,142 feet Plugs measured N/A feet true vertical 11,142 feet Junk measured 10,781 (fill) feet Effective Depth measured 10,781 feet Packer measured 10,486 feet true vertical 10,781 feet true vertical 10,486 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 40' 40' -ammo* Surface 2,029' 11 -3/4" 2,029' 2,029' 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED SAN 10 2.O3 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# / L -80 10,501' MD 10,501' TVD Tripoint Packers and SSSV (type, measured and true vertical depth) AS1 -X 10,486' MD & TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 50 300 500 1,150 300 Subsequent to operation: 70 200 800 1,200 250 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development El - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -162 Contact Chad Helgeson Email chelgeson @hilcoro.com Printed Name 1//547.'',.7--- Chad Helgeson Title Operations Engineer Signature Phone 907-777-8405 Date 1 c/ _/f _. Form 10 -404 Revised 10/2012 nn R �} 1 GI NABD OCT 26 Q� v 11 11, Submit Original Only U • �� Hilcorp Alaska, LLC ^ ^^^~'~~^ n ~ ^ ^^~~^~^~~~« ~~~~~~ ~~~~^` Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 21-27 50'138-10156-00 161-010 8/26/12 9/27/13 8/26/2012 - Sunday MIRU, RU to production tree. Reverse circulate well with PW and killed well. 8/27/2012 - Monday Nipple down production tree. Nippling up BOPs while finishing rigging up. 8/28/2012 - Tuesday Test BOPs (250 psi low - 3,000 psi high). Witness waived by Jim Regg, AOGCC. RD test joint and equipment. RU and RIH with Pollard wireline for gauge/CCL. Go back in hole and make cut at 10,651'. POOH with E-Line. Screw into liner hanger. Pull free and lay down. 8/29/2012 - Wednesday RU flow line. POOH and lay down 2-7/8"6.4#L8O|@T(SCC) tubing. At1,QOO' starting tm get gas at surface. Stab TIW, fill hole with water. 8/30/2012 -Thursday Finish POOH and laying out production string. PU and R|H with burning shoe /5.7SO"C>D/4.75O"|D\,vxashpipe(5.75O"OD/ 5.125" ID), and workstring (2-7/8" PH6 7.9#). BHA Length 260.57'. 8/31/2012 - Friday Finish RIH with 2-7/8" workstring and burning shoe. Tag upat1{\S3G' (top ofp@R) wash over and burn on packer. 9/01/2012 - Saturday Milling. Unable to get torque on mill. Adjusted WOB and rpms several times. PU and slack off. Mill would not get a bite. Spotted 20 bbl pill on bottom. POOH. Shot fluid level - 2,389'. 9/02/2012 - Sunday Finish POOH. Break out burning shoe, make up new shoe. Work on and adjust the rig brakes, rig maintenance. Go in hole with work string, BHA, and new burning shoe. 9/03/2012 - Monday Finish TIH. Mill on packer. Was able to establish partial returns. Milling/circulating pumping sweeps periodically. Keeping pits full. 9/04/2012 - Tuesday Pumped total of 265 Bbls before obtaining circulation. Stopped burning over packer. RD power swivel, layed down kelly joint. GO<�Hw/161stands�f2-�/@"VV�. LD'ars,vvash-pi�e'ointandburnyhoe. 8urnshoeshom/edvery|itt|esignofvvea� ' w/ jars, ' appears to be turning on obstruction. MU test sub on test joint. Started BOP test. Secured well, SDFN. 9/5/2012 - Wednesday Finished testing BOPs and gas detection system. (Witness waived by Jim Regg, AOGCC. 250 psi low - 3,000 psi high.) MU E- 8032 Retrievable PBR retrieving spear. TIH w/ spear on bumper jars, 6 drill collars, and 161 stands of2-7/8"P11OWS. PU 4 more singles. Tagged top of PBR @ 10,535'. Latched PBR with Spear. PU to 2 thousand over string weight and made 4 turns to the right. Release P@R and SOOHw/2 stands of2'7/Q"WS. Secured well, SDFN. 9/6/2012 - Thursday • • SOOH w/163 stands of 2 -7/8" P110 WS. LD retrieving tool and PBR assembly. MU burn shoe on 1 jt of wash pipe. TIH w/ burn shoe, 1 jt of wash -pipe, bumper jars, 6 drill collars and 162 stands of 2 -7/8" WS. Tagged packer with 6' out of last stand. Secured well, SDFN. 9/7/2012 - Friday MU power swivel. PU 1 jt of 2 -7/8" P -110 WS. Tagged top of packer. Started burning over. Made 2.5' of hole. RD power swivel. LD 1 jt of 2 -7/8" WS. SOOH with 2 -7/8" P -110 WS. SOOH w/ 60 stands. Secured well, SDFN. 9/8/2012 - Saturday Continued SOOH w/ 2 -7/8" P -110 WS and Burn shoe. LD wash pipe and burn shoe. Burn shoe showed signs of wear on inside lip only. MU spear loaded with 3" grapple. TBIH w/ spear and 2 -7/8" WS. Tagged top of packer and ran spear down inside packer. Engaged spear /grapple and started to pull packer. Pulled up 140K on spear, 50K over string weight. Could not release spear. Secured Well, SDFN. 9/9/2012 - Sunday MU power swivel. Stacked 10K down on spear. PU and pulled 125K on spear. RD power swivel. SOOH w/ 2 -7/8" P -110 WS and spear. LD spear with 3'3" of packer on spear. MIRU Pollard Wireline Unit. RIH w/ 4" magnet. Tagged top of packer at 10,545' wlm. POOH. RBIH. POOH. Recovered 6" long by 1" wide peice of metal. RBIH. POOH. Recovered 2 small peices of metal. MU 6" LIB. TIH. Made down to 7,850' wlm. POOH. Sticky on way. 9/10/2012 - Monday MU 4 blade junk mill. TBIH. Tagged top of packer @ 10,547'. MU power swivel. Started circulating fluid. Started milling, made 1 ft of solid milling. Milled 3'. Made 4 more feet of solid milling. Stopped milling. Mixed a heavy visc sweep. Pumped full circulation volume. Recovered metal shavings and debris. RD power swivel. SOOH with 60 stands of 2 -7/8" P -110 WS. 9/11/2012 - Tuesday Finish SOOH w/ remaining 107 stands of 2 -7/8" P -110 WS and junk mill. MIRU Pollard Slick -line. RIH w/ 4" magnet. Tagged top of packer @ 10,555'. POOH. Recovered a peice of slip. TBIH. Tagged same. POOH. Recovered nothing. MU 4.75 LIB. RIH, tagged top of packer same depth. Stroked and POOH. Showed marks on left side. MU 2" gauge ring. RIH. Tagged same depth, worked up and down for 40 mins, could not get to go down. POOH. Gauge ring had metal marks across face. RDMO Pollard Unit. Aurora Well Service tested BOPs and gas detection system. (Witness waived by Jim Regg, AOGCC. 250 psi low - 3,000 psi high.) Secured well, SDFN. 9/12/2012 - Wednesday TIH w/ 2 -7/8" Reg spear loaded with 2.43 grapple. Tagged top of fish @ 10,555'. Worked up and down 10 -12 times, swallowed 4' on second up and down movement. Jarred down on fish. Stacked out 8' deeper than first tag depth @ 10,563'. SOOH w/ 2 -7/8" P -110 WS. LD spear, no fish. Bull nose on spear showed markings of being inside tbg but not around grapple on spear. Secured well, SDFN. 9/13/2012 - Thursday MIRU Pollard Slickline. RIH w/ 5.75" LIB. Tagged top of fish at 10,560' wlm. POOH. RBIH w/ 1 -3/4" blind box. POOH. RBIH w/ 3.75" LIB. Tagged same. POOH. RBIH w/ 4.5" LIB. Tagged same. POOH. All LIB's showed same impression. RDMO Pollard Slickline. MU 4 Blade Junk Mill. TIH w/ mill, jars, 6 drill collars, accelerator jars, and 166 stands of 2 -7/8" P -110 WS. Tagged TOF @ 10,559 '. Started milling, mill showings signs of milling with 2 -3K lbs down on mill, any more weight and starts spinning down hole. Made about 5" from 4 -6 pm. Secured well, SDFN. 9/14/2012 - Friday Continued milling on packer. Tagged TOF @ 10,560'. Milled down 1'. Pumped 5- 20 Bbls gel sweeps. Pumped total of 540 Bbls of produced saltwater. SOOH w/ 130 stands of 2 -7/8" P -110 WS. • • • 9/15/2012 - Saturday Finished SOOH w/ remaining 67 stands of 2 -7/8" P -110 WS. LD double boot baskets and mill. Outside of mill worn out, had a 3.5 center ring un- touched on mill. MIRU Pollard Braided line Unit. MU 3.75" LIB with centralizer. RIH, tagged top of packer @ 10,568' wlm. Stroked down one time. POOH. Had impression of 3.5" marking. MU Spear on 2" JDC. RIH, tagged same. Tried to beat spear inside 3.5 ", no progress. POOH. MU 1.5" LIB. RBIH, tagged same, tried to work down, no progress. POOH. Had metal marks, looked like slip marks. MU 4" magnet. RIH, worked up and down on top of fish. POOH. Recovered very little metal shaving. RDMO Pollard Braided line Unit. MU 2" ID mill /spear on double boot basket, bumper jar, 6 drill collars, accelerator jars and 45 stands of 2 -7/8" P -110 WS. Secured well, SDFN. 9/16/2012 - Sunday Continued TIH w/ remaining 116 stands of 2 -7/8" P -110 WS. Tagged top of packer @ 10,560'. MU power swivel on two 5' pups. Engaged swivel and started milling on center of packer. Made total of 4' before mill stopped. RD power swivel and LD pups and a single jt of 2 -7/8" WS. Pumped five 5 Bbl gel sweeps during milling. Pumped a total of 424 Bbls on the day. Secured well, SDFN. 9/17/2012 - Monday SOOH w/ 2 -7/8" WS. LD double boot basket and 2" ID Mill. Mill had markings of being inside pipe. MIRU Pollard Braided Line Unit. RIH w/ 4.5" centralizer and 2.5" magnet. Tagged obstruction @ 10,542' wlm. POOH. Recovered a metal ring with threads on inside and out. RBIH. Tagged same. POOH. No recovery. MU 3.5" GR and bait sub w/ 4' knight spear loaded with 2 -7/8" grapple. RIH. Tagged top of packer @ 10,542'. PU and had 500 Ibs more pick up weight. POOH. Recover packer and tbg below with Poor Boy overshot, 51' total length. MU 3.75" LIB. RIH. Tagged top of tbg @ 10,593'. POOH. LIB showed perfect impression of 2 -7/8" tbg. MU 4.5" GR and 4.5" bait sub with Knight overshot loaded with 2 -7/8" grapple. Tagged tbg @ 10,593'. PU had 350 Ibs over pick up weight. POOH. Recoverd tbg with double bowen overshot and tbg tail. RDMO Braided Line Unit. 9/18/2012 - Tuesday Tested BOPs and gas detection system (John Crisp, AOGCC, witnessed BOP inspection: 250 psi low - 3,000 psi high). MU 4' spear loaded with 2 -7/8" grapple. TIH w/ spear, bumper jars, 6 drill collars, accelerator jars and 67 stands of 2 -7/8" P -110 WS. Left EOT @ 4,496'. Secured well, SDFN. 9/19/2012 - Wednesday TIH w/ remaining 100 stands of 2 -7/8" P -110 WS, and PU 3 more single. MU power swivel and tagged top of fish @ 10,628'. Pushed spear down 4' and engaged grapple inside 2 -7/8" fish. PU 30K over string weight and packer started moving up hole dragging at 104K Ibs. RD power swivel. SOOH dragging every casing collar up to 118K Ibs. SOOH w/ total of 168 stands of 2- 7/8" WS. LD Brown packer and 5 -1/2" joints of tbg tail. Tbg had 8 -10" slit 6' below packer. Tbg tail was also corked screwed and full of sand. Last joint was 15.7' long. Secured well, SDFN. 9/20/2012 -Thursday MIRU SL unit. RIH w/ 3' drive down bailer and tag bottom at 10,792' slm. POOH w /sample of sand and gravel. RBIH w /bailer and tag at 10,794' slm. POOH w /sample of sand, garvel and lead. RBIH w /bailer and tag 10,778'. Beat bailer down to 10,794' slm. Bailed down to 10,796' slm. POOH w /sample of sand and gravel. RBIH w /bailer and tag 10,796' slm. Bailed to 10,798' slm. POOH w /sand, gravel and baseball size piece of rubber. RDMO SL unit. TIH w/ 77 stands of 2 -7/8" work string with mule shoe. Secured well, SDFN. 9/21/2012 - Friday MIRU E -line. RIH w/ CCL and Gamma Ray logging tool and tagged TD at 10,775' elm. Logged from bottom to 8,000' elm. POOH. RDMO E -line Unit. TIH w/ 83 stands of 2 -7/8" work string and tagged hard @ 10,775'. Circulated 3 sweeps around clean. Secured well, SDFN. • • 9/22/2012 - Saturday TIH w/ 7 stands. Tagged bottom @ 10,781'. POOH LD 2 -7/8" P -110 WS. LD total of 347 joints. MIRU Pollard E -Line Unit. PU 4' gun/ CCL. Perforated first 4' of second interval from 10,764'- 10,768'. POOH. MU second gun. RIH. Perforated second interval from 10,728 ° - 10,763'. 9/23/2012 - Sunday PU third gun. RBIH to desired depth. Completed second interval. Perforated from 10,708'- 10,728'. POOH. PU fourth gun. RBIH to desired depth. Perforate top interval from 10,683'- 10,703'. POOH. RDMO Pollard E -Line Unit. Fluid level came up from 5,400' to 850'. Set pipe racks. Unloaded and tallied 134 jts of 3 -1/2" 8 RD production string. Swapped pipe rams in BOP's and tested. Received and unloaded packer and gas lift mandrels. MU packer and BHA, WLR guide, 2' pup, XN nipple, 2' pup, AS -1X packer with On /Off tool assembly, 1 jt of 3 -1/2" tbg and first gas lift mandrel. Picked up total of 4 mandrels and total of 100 jts of 3 -1/2" 8 RD tbg. Secured well, SDFN. 9/24/2012 - Monday SITP -80, SICP -80, Blew well down. Continued TIH w/ 3 -1/2" production string and GL mandrels. Landed and set AS -1X Packer @ 10,492'. PU to 125K Ibs on packer to ensure set. Landed tbg hanger w/ 9,800 Ibs of compression on packer. Tested and charted tbg and casing for 30 mins @ 2,500 psi. Both tested good. Started rigging down WOR and equipment down. Secured Well, SDFN. 9/25/2012 - Tuesday Continued RD WOR rig. No pressure on well. Set BPV in hanger. ND BOP's and NU Wellhead. Cleaned pits and floor. 9/26/2012 - Wednesday Continued rigging down WOR Rig. Moved rig and all equipment off location. Hauled 7 Toads to Happy Valley A pad. Cameron wellhead hand pulled back pressure valve. Construction moved in and hooked up wellhead to sales and gas lift. 9/27/2012 -Thursday MIRU SL. Pulled prong and plug. Fluid level @ 1,100' slm. Started flowing well. • n Re ' Well SRU son 21 iv 27 Unit II SCHEMATIC Last Swa Completed r 09/24/12 PTD: 16 01 Hitco.P Awake, LLC API: 50 -133- 10155 -00 wcs =1g cL =tea' CASING DETAIL J ' Size WT Grade Conn ID Top Btm . IL 20" - - - 40' , 11 -3/4" 47 1-55 8RD 11 Surface 2,029' 20 @4 29 P -110 BTC 6.184 Surface 160' 26 N -80 BTC 6.276 160' 1091' 23 N -80 BTC 6.366 1091' 4783' 7 26 N -80 BTC 6.276 4783' 6583' 29 P -110 BTC 6.184 6583' 8398' 4 b. 29 _ P -110 8RD 6.184 8398' 11,142' 113/4 " @ 2,02g TUBING DETAIL L____111 1 3 -1/2" 1 9.3 I 1 -80 1 8RD EUE 1 2.992 Surface 10,501' r W 2 JEWELRY DETAIL No Depth ID OD ItPrn E 3 1 3,305' 2.992 5.313 GLSFO -1 Mandrel, Port 12 2 5,606' 2.992 5.313 GL SFO -1 Mandrel, Port 12 3 7,181' 2.992 5.313 GL SFO -1 Mandrel, Port 12 4 8,337' 2.992 5.313 GL SFO -1 Mandrel, Port 16 l i) 4 5 9,237' 2.992 5.313 GLSFO -1 Mandrel, Port 16 6 9,951' 2.992 5.313 GLSFO -1 Mandrel, Port 16 7 10,443' 2.992 5.313 GL SFO -1 Mandrel, Orifice 20 8 10,485' 2.813 5.75 Tripoint T -2 On /Off Tool 1 9 10,486' 3 5.875 Tripoint AS1 -X packer 10 10,500' 2.813 3.9 XN Nipple 11 10,501' 3 4.125 WL Entry Guide I n 6 PERFORATION DATA I 7 Zone Top(MD) Btm(MD) Top(TVD) Btm(TBVD) Accum Last Present Notes SPF Perf. Date Condition 10,672' 10,673' 10,672' 10,673' 5 5/2/1961 SQZD 8 H1 10,676' 10,696' 10,676' 10,696' 4 5/4/1961 Open 10,683' 10,703' 10,683' 10,703' 6 9/22/2012 Open 3 -3/8" H2 /H3 10,708' 10,768' 10,708' 10,768' 6 9/23/2012 Open 3 -3/8" 1 l # 10,710' 10,773' 10,710' 10,773' 4 5/4/1961 Open _11 m- f . 9 H4 /H5 10,778' 10,805' 10,778' 10,805' 4 5/4/1961 Open MN = Sgzd 10 p ■ 11 , =H -1 TOF tagged @ 10,768' - 9/22/12 H -2/H -3 H -0 /H -5 15 ft of original - completion left in - bottom of well, unknown depth 7" @11,142 4 ', 7" Cement Bond Log TD = 11,142' PBTD = 11,000' 10,195' - 10,280' - Good 10.365' - 10,432' - Fair Directional Data: 10,575' - 10,604' - Good max hole angle = 2.25° at 2035' MD 10,675' - 10,710' - Fair Updated by DMA 10 -25 -12 14 5? CA.. ZI Z? • P.M /l6 ( 0too Regg, James B (DOA) From: Donnie Huffman <donnierhuffman@yahoo.com> �ti &'r # Sent: Friday, September 21, 2012 1:12 PM To: Regg, James B (DOA) Subject: Re:AWS Bop test 9/17/2012 I have spoken to the rental company which we rent the other manifolds from, it is NOT recommended that we use cheaters or pipe wrenchs to close these valves. I have spoken to cameron about going thruogh the manifold for Aurora well service, we will have this taken care of before we test at happy valley. Sorry I havnt replied yet. From: "Regg, James B (DOA)" <jim.regg@alaska.gov> To: Donnie Huffman <donnierhuffman@yahoo.com>; Tom Fouts- (C) <tfouts@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Chad Helgeson <chelgeson@hilcorp.com>; "rodlmccoy@aol.com" <rodlmccoy@aol.com>; "awhudgens75@yahoo.in" <awhudgens75@yahoo.in> Cc: "Crisp, John H (DOA)" <john.crisp@alaska.gov> Sent: Friday, September 21, 2012 12:19 PM Subject: RE: AWS Bop test 9/17/2012 Inspector indicated that choke manifold valves had to be greased AND cheated tight to hold test pressure. Have you been able to locate information as requested regarding choke manifold valves? Request highlighted below. Jim Regg AOGCC 333 W. 7th Ave,Suite 100 SCANNED JAN 1 0 2017, Anchorage,AK 99501 907-793-1236 From: Crisp,John H(DOA) Sent: Wednesday, September 19,2012 10:05 PM To: Donnie Huffman;Regg,James B (DOA);Tom Fouts-(C);Donna Ambruz; Stan Golis;Chad Helgeson;DOA AOGCC Prudhoe Bay;Brooks,Phoebe L(DOA);rodlmccoy@aol.com;awhudgens75@yahoo.in Subject: RE: AWS Bop test 9/17/2012 Mr. Huffman,thanks for your help in scheduling your BOP test so that AOGCC witness was easily accomplished.Difficult to witness flange integrity due to the rain, we tried as best we could. Rig crews&Rig Manager did a great job. My understanding is that drilling at Happy Valley is planned after your successful WO of this well. As reported on your AOGCC test form there were several valves in the choke manifold that had to be greased to hold test pressure,not many choke manifolds pass without this being performed.My question is: does the choke valve manufacturer recommend hard closure to the extent of using a pipe wrench to cheat the valves closed?This seemed to be the case on all valves in the choke manifold.Thanks for your help in my understanding this issue. Again thank you for taking me all over the Field to witness SVS tests on 32-B9&42-4.Again it was a long day with travel& continuous rain.My question to AOGCC Inspection Team was if the procedure that Marty(instrument tech)used was the same procedure that had been used in the past with other Inspectors for SRU SVS systems. The reason that I wanted input from our Team was due to the porta power pump being utilized to pressure the pilots&then closing flowline root valve to bleed the pilot to trip pressure. It seems that no AOGCC Inspector has witnessed this procedure with the pump. Maybe I could get a number from you so I can call the IT for input&a little furthur explanation of test procedure. 1 It is good to see the Hilcorp Team working hard to increase production in Swanson River nit&I wish you&your Team very good luck with all your Operations. From: Donnie Huffman [donnierhuffman@yahoo.com] Sent: Wednesday, September 19,2012 2:21 PM To: Regg,James B(DOA); Tom Fouts-(C);Donna Ambruz; Stan Golis; Chad Helgeson;DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA);rodlmccoynaol.com; awhudgens75 a,yahoo.in Subject: AWS Bop test 9/17/2012 2 • • 57 rr „. ( _ SEAN PARNELL, GOVERNOR 1 ` ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 , Q 1 b Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 21 -27 Sundry Number: 312 -162 Dear Mr. Golis: StAiNED MAY 2 2 2012 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this Z' day of Ma 2012. Y Y� Encl. • II st.,��/ RECEIVED STATE OF ALASKA 7 PR 2 4 201 t ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod p .(j Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing 0• Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: COWB -RC lower -new GLV V. 2. Operator Name: 4. Current Well Class: 5. Permit to Dry Number. Hilcorp Alaska, LLC Development Ei . Exploratory ❑ 161 -010 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number 3800 Centerpoint Drive, Ste 100, Anchorage, AK 99503 50- 133 - 10155 -00-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership cianges: Swanson River Unit (SRU) 21 -27 • Spacing Exception Required? Yes ❑ No 9. Property Designation (Lease Number): 10. Field /Pool(s): Swanson River Field (FEDA028406) 4 Swanson River Field / Hemlock Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 1 11,142 • 11,142. 11,000 11,000 N/A 10,799 (fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 40' 40' Surface 2,029' 11 -3/4" 2,029' 2,029' 3,070 psi 1,510 psi Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -7/8" 6.5# N -80, 7.9# L -80, 6.5# N -80 10,760 Packers and SSSV Type: Baker SB -3 & Brown HS -16 -1 Packer Packers and SSSV MD (ft) and TVD (ft): 10,578' & 10,655' MD; 10,578' & 10,655' TVD 12. Attachments: Description Summary of Proposal IS 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 5/19/2012 Commencing Operations: Oil 0 . Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Golis Printed Name Stan Golis /� Title Operations Manager Signature 5 r" t-•- tire*: Phone 777 -8300 Date L i / i4 (zc 1 Z—_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3t 2,,,,, 1 D Plug Integrity ❑ BOP Test le Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5 op tt'5f' 3120a psi 7 Subsequent Form Required: • / 12 ' 4' 424- / APPROVED BY Approved by �( W y A , � CM ISSIONR 7'.... Z 7 / �� /""�� O E THE COMMISSION Date: 10/14: ip DMS MAY 2 2101Z ) ."_ � :,r t Form 10-403 Revised 1/2010 A Submit in Duplicat 61/�/�/ O RIGIN • Swanson River SRU 21 -27 April 23, 2012 Hilcorp Alaska, LLC OBJECTIVE: • Active oil producer. Pull tubing, cleanout wellbore to 11,000' MD. Recomplete lower in the Hemlock sands based on . Gamma Ray Neutron electric log. Run 3 -1/2" production tubing with redesigned gas lift valves to lift more fluid. Current BHP: 3100 psi @ 10,676' MD Max Downhole Pressure: 3100 psi @ 10,676' MD (Based on offset well pressure surveys) MASP: 2035 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) per T ✓D V R ,Ct P (� OCEDURE SUMMARY: �`� 41..) ,-- - v 5 f C LJ _ API/ 1. MIRU pu itl ng unit. Load casing & tubing with 8.7 ppg field salt water to kill Well. ND xmas tree. NU BOPs. Pressure test BOPs to 250 psi low /3000 psi high. 4 ab& 10L7c h' S /k7 a el vi � .. of /3oP f -- 2. RU e-line. Make gauge ring /junk basket/CCL run to 10,600' MD. POOH. PU and RIH with 1- 11/16" radial torch cutter and make cut @ 10,600' MD. POOH. Make second run with 1- 11/16" radial torch cutter to make cut at 10,545' MD. RD e-line unit. 3. POOH while laying down 2 -7/8" production tubing. 4. PU and RIH with overshot/ grapple & workstring. Tag top of cut tubing at 10,545' MD. Latch fish. Pick up to snap out of Model E snap -latch seal assembly at 10,577' MD. 5. POOH. Laydown fish, overshot & grapple. 6. PU and RIH with burning shoe, washpipe & workstring. Tag top of Baker SB -3 packer @ 10,578' MD. Burn over packer. 7. POOH. Laydown burning shoe & washpipe. PU & RIH w /overshot and grapple. Tag top of fish. Latch fish. POOH. Laydown fish. 8. PU & RIH w /overshot & grapple. Tag top of fish @ 10,600' MD. Disengage overshot @ 10,645' MD. POOH. LD overshots & fish. 9. PU and RIH with washover shoe, washpipe & workstring. Tag top of Brown HS -16 -1 packer @ 10,655' MD. Wash sand off packer. 10. PU & RIH w /overshot & grapple and jars. Tag top of fish. Latch fish. Jar to release packer. POOH. Laydown Brown HS -16 -1 packer & tailpipe. 11. RU e-line unit. Make gauge ring /junk basket/CCL run to 11,000' MD. Run Gamma Ray Neutron electric log from 10,000' ( + / -) MD - TD. 12. RIH with 3 -3/8" TAG guns loaded 6 SPF and 60° phasing to make required perforating runs to perforate 10,676' - 10,696' ( +1 -) MD; 10,710'- 10,773' ( + / -) MD; and 10,778'- 10,805' ( + / -) MD per GRN log results. • RD a -line unit. 13. RIH with AS- 1Xpacker, dummy GLVs and remaining 3 -1/2 ", 9.3 ppf, L -80, EUE T &C tubing. Set packer --° @ ( + / -) 16:6 MD. Per W. Aubert 12 -10 -10 e-mail, SCSSSVs are not required in the Swanson River Field. 14. Pressure test casin_ g to 1500 psi for 30 minutes with chart recorder. 15. ND BOPs. NU xmas tree. - T � 16. RDMO workover rig and equipment. 17. Turn well over to production. Well Identifier REVISED BY: DMA 04 -23 -12 11 SRU 21 -27 We SRU 211 27Unit A al Welibore Schematic Completion Landed 10/04/09 Hileorp Alaska. I.I.C. RKB =199' CASING AND TUBING DETAIL GL =184' SIZE WT GRADE CONN ID TOP BTM. ill 1, 20" - - - 1 ` 11 -3/4" 47 J -55 8RD 11.00 Surface 2,029' 7" 29 P -110 BTC 6.184 Surface 160' 20 " @4t7 ;; w? 7" 26 N -80 BTC 6.276 160' 1091' 7" 23 N -80 BTC 6.366 1091' 4783' ''" ' ". 7" 26 N -80 BTC 6.276 4783' 6583' ;', 7" 29 P -110 BTC 6.184 6583' 8398' �'; • 7" 29 P -110 8RD 6.184 8398' 11,142' r L Tubing 11 -314" @ 2029' 2 -7/8" 6.4 L -80 IBT(SCC) 2.441 Surface 10,621' MR ∎ 1 2 -7/8" 7.9 L -80 PH -6 2.323 10,627' 10,645' 2 -7/8" 6.5 N -80 EUE 8RD 2.441 10,647' 10,820' I 2 I JEWELRY DETAIMINIP MB i 3 NO. Depth ID OD Item • G A 1 4382' 2.441 4.750 SFO -1 GLM w /1/4" valve [installed 10/05/09] re 1 4 f� 2 6513' 2.441 4.750 SFO -1 GLM w /1/4" valve [installed 10/05/09] �: 5 iO J 3 8684' 2.441 4.750 SFO -1 GLM w /1/4" valve [installed 10/05/09] 4 10,525' 2.441 4.750 SFO -1 GLM w/3/8" valve [installed 10/05/09] 6 = - 5 10,559' 2.410 4.630 Tubing locator w/ 12' of seals (spaced 4.5' above PBR) 7 6 10,564' 3.250 4.300 12' PBR 7 10,577' 2.425 4.630 E- Anchor A V 8 10,578' 2.441 5.680 Baker 2- 7/8 "x7" SB -3 Packer A' Kr 6 9 10,583' 2.441 2.875 XO from packer to 2 -7/8" tubing � - 10 10,619' 2.313 2.875 "X" Nipple (2.313" Min ID) f 9 „i- i A 11 10,625' 2.438 4.250 Overshot WLEG (Non- sealing) I in 10 . r II JEWELRY DETAIL (LEFT IN HOLE) NO. Depth ID OD Item Radial can L 11 12 10,627' 2.323 2.875 Cut joint (2 -7/8" 7.9# PH -6 tubing) (2.229" Drift) 2-7/8" PH -6Jt "------ I - 12 13 10,645' 2.250 5.750 Double Bowen 150 Overshots (Sealing) ini 14 10,647' 2.441 3.500 Cut joint (2 -7/8" 6.5# 8RD tubing) (7.78' long) I. 15 10,655' 2.500 5.875 Brown 2- 7/8 "x7" HS -16 -1 Packer (Stuck) I ;:� 13 16 10,724' 2.313 3. Camco "D" Nipple OD cut R 17 10,820' - - Venturi Shoe 2 -7/8" 8RD Jt " t I 14 *ALL JEWELRY HAS MOVED 60' DOWNHOLE* litlimi ,( a ,r 15 CURRENT PERFORATION DATA (MD) �� Zone To • Btm DATE S • f Comments Hl 10,672' 10,673' 5 -2 -61 • 5 2 -1/8" WSO #1 H-1 111 10,676' 10,696' 5 -4 -61 4 2 -1/8" capsule H2/3 10,710' 10,773' 5 -4 -61 4 2 -1/8" capsule H4/5 10,778' 10,805' 5 -4 -61 4 2 -1/8" capsule 16 J H - 2/I+3 1 7" Cement Bond Log Tube Punch 10,791' - 10,797'_4,. - H 41..1-5 10,195' - 10,280' - Good 10.365' - 10,432' - Fair CEV Valve -_,„,,,, 4 10,799. 10,575' - 10,604' - Good 17 10,675' - 10,710' - Fair 7" @ 11,142' 4*,',....... k TD= 11,142' PBTD= 11,000' Directional Data: max hole angle = 2.25° at 2035' MD SRU 21 -27 Schematic 04 -23 -2012 Updated by DMA 04 -23 -2012 S T T T -27 Swanson River Unit KU Well SRU 21 -27 II Completion Landed 10/04/09 Proposed Wellbore Schematic PTD: 161 -010 Hilrnrp Alaska. 1 1.0 RKB =199' CASING AND TUBING DETAIL GL =184' 1 L SIZE WT GRADE CONN ID TOP BTM 20" @ 40' - 20" - - - 40' 11 -3/4" 47 1 -55 8RD 11 Surface 2,029' 7 29 P -110 BTC 6.184 Surface 160' 7" 26 N - BTC 6.276 160' 1091' d IN. 7" 23 N -80 BTC 6.366 1091' 4783' 11 -3/4" @ 2029' li 1 7" 26 N -80 BTC 6.276 4783' 6583' 7" 29 P -110 BTC 6.184 6583' 8398' 1 2 7" 29 P -110 8RD 6.184 8398' 11,142' TUBING 1 3 3 - 1/2" 9.3 N - 80 2.992 Surface ± 7 JEWELRY DETAIL 4 NO. Depth ID OD Item 1 ± 3,000' 2.992 5.313 GLV 2 ± 5,000' 2.992 5.313 GLV I la]5 GLV 3 ± 5,500' 2.992 5.313 4 ± 7,000' 2.992 5.313 GLV I 6 5 ± 8,000' 2.992 5.313 GLV 6 ± 9,000' 2.992 5.313 GLV 7 7 ± 9,500' 2..992 5.313 GLV 8 ± 10,000' 2.992 5.313 GLV 9 ± 10,500' 2.861 2.875 AS -1X packer 1 8 PERFORATION DATA Accum Last Present . "r_i,, 8 - 9 Zone Top Btm Condition Notes T = Sqzd SPF Perf. Date . ._. „ z H -1 H1 10,672' 10,673' 5 5/2/1961 SQZD H1 10,676' 10,696' 4 5/4/1961 Open H1 ±10,676' ±10,696' 6 Future H-2/H-3 H2 /H3 10,710' 10,773' 4 5/4/1961 Open H2 /H3 ±10,710' ±10,773' 6 Future H4 /H5 10,778' 10,805' 4 5/4/1961 Open H -4/H -5 H4 /H5 ±10,778 10,805' 6 Future 7" Cement Bond Log 10,195' - 10,280' - Good 10.365' - 10,432' - Fair 10,575' - 10,604' - Good 7" @11'142 10,675 - 10,710' - Fair TD = 11,142' PBTD = 11,000' Directional Data: niax hole angle = 2.25° at 2035' MD SRU 21 -27 Proposed Schematic 05 -18 -2012 Updated by TDF 05 - 18 - 2012 • • Swanson River SRU 21 -27 Current 02/09/2012 Hilenrp %Imola. I.1.4. Swanson River Tubing hanger, Shaffer T55- SRU 21 -27 AJO, 7 X 2 7/8 IBT lift and 11 3/4 X 7 X 2 7/8 BHTA Bowen 3 ", ,, 2 7/8 IBT -M susp, w/ 2 %2' 2 9/16 5M FE 0 type H BPV profile, 3/8 control line Valve swab, WKM -M 2 9/16 5M FE, HWO, AA 0 o O 0 Valve wing, WKM -M A _ _. _ A - 2 9/16 5M HWO, AA r I � , �i � I } l • o a �� Tee, stdd, 2 9/16 5M X Valve upper master, 0 • WKM -M 2 9/16 5M FE, 29/165M ` x,0 HWO, AA Valve lower master, 1 WKM -M 2 9/16 5M FE, o • HWO,AA Adapter, Shaffer -AJO, 7 1/16 5M stdd X 2 9/16 _ 5M, w/ 1- %control line r exit 6'/4' seal pocket _ Ground Level wINIII" Ill e. Oc 11 IN 1 I I 1 Valve, WKM -M , 2 1/16 e 5M FE, HWO, U 0 O i o l r , t 41 . JI,Un ILI'.. Qty 2 Tubing head, Shaffer ° T55 -LI, 13 5/8 3M X II I iii 71/165Mw/2- 21/165M i � y SSO, 7" Type 1 secondary ��- seal in head _ /111 — ■i Valve, plug, Rockwell, 2" AA Casing head, Shaffer KD, IMO. ; I1.1. 13 5/8 3M X 11 3/4 SOW, w/ 2- 2" LPO, 7" KD slips and packoff assy in head or • e . itii Swanson River SRU 21 -27 BOPE 03/02/2012 Hile rp ila4.5. I.i.0 SRU 21 -27 11 i Iti nl in rq Fit ItTil Annular Preventer 7 1/16 5M 11I11i ri ' 7 1/16 5M I� Pipe rams V 9 cli ®® �lo Blind rams Choke and Kill lines IN 2 1/16 5M w/ 2" Unbolt I I connections for choke and 1 ii iisi It I, kill hoses m ti r t Co 1 r V ' = 7 1/16 5M I E o ( i e l • @, - r ° ® I i., I, Vi [* i ii t e � i' 1111111.111 - Iii 111 Ground Level ' ' j ' 11 • li l_ IU i 1 p o�)�] ■■ III ® e ��ol 11'x' L] I Ili In emu• I� 111 i III III 01 10 III41 Nu i Page 1 of 2 • Schwartz, Guy L (DOA) From: Stan Golis [sgolis @hilcorp.com] Sent: Friday, April 27, 2012 9:15 AM To: Schwartz, Guy L (DOA) Cc: Regg, James B (DOA); Ferguson, Victoria L (DOA); Clint Chanley; Tom Fouts - (C); Larry Greenstein; David Boelens (dboelens @aurorapower.com); paullangley @internationalcompletion.com Subject: RE: SRU 21 -27 ( PTD 161 -010) Attachments: SRU 21 -27 BOP drawing.docx; SRU 23 -15 BOP drawing.docx Guy, Attached is the BOP drawing that we plan to use on the SRU 21 -27, a rental 7- 1/16" x 5000 psi BOP stack, in place of Aurora's 11" x 3000 psi stack. The rental stack will be delivered in Anchorage on Sunday, April 29. Our intention is to start using it when we rig up on the next well for the Aurora rig which is the SRU 23 -15. The Aurora rig is currently on the SRU 21 -22 and should finish up early next week on this job. Thanks. Stan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, April 25, 2012 2:54 PM To: Stan Golis Cc: Regg, James B (DOA); Ferguson, Victoria L (DOR) Subject: SRU 21 -27 ( PTD 161 -010) Stan, I have a new sundry for SRU 21 -27 RWO with a mislabeled BOP stack. ( Unless the CUDD unit is doing the work I thought Aurora rig was at SRU.) Please see below email. Might be a good idea to identify the workover rig in the procedure too. It is confusing for me to figure out if you are changing rigs or if it is a typo. Comments on procedure: 1. Set BPV before pulling tree off. TWC to nipple down BOP and nipple up Tree. 2. Need proposed completion schematic . Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 18, 2012 9:26 AM To: Stan Golis Cc: Regg, James B (DOA) Subject: FW: BOPE configuration Stan, Per the email below can you start labeling the BOPE /wellhead sketch that is supplied with the sundry to include the associated rig. That should take care of the miscommunication that happened. Guy Schwartz Senior Petroleum Engineer AOGCC 4/27/2012 Page 2 of 2 • 793 -1226 (office) 444 -3433 (cell) From: Regg, James B (DOA) Sent: Tuesday, April 17, 2012 5:46 PM To: Schwartz, Guy L (DOA) Subject: FW: BOPE configuration Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Doc Holliday - (C) [mailto:rholliday @ hilcorp.com] Sent: Tuesday, April 17, 2012 5:42 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Grimaldi, Louis R (DOA) Cc: paullangley @zplenergy.com Subject: BOPE configuration To AII, I am sending this email in regards to discrepancies concerning the Sundry Approval for the Aurora rig currently working in the Swanson River Field for Hilcorp. The original Sundry requests covered the Cudd jacking unit that was supposed to perform the well work in Swanson River. Last minute changes moved the Cudd unit to the King Salmon Platform and the Aurora rig was brought to Swanson River. The Cudd unit uses a 7 1/16" x 5m stack versus the 11" x 3m stack used on the Aurora rig. An assumption was made in error that the changes could be rectified on the BOPE test reports submitted after each test. Mr. Paul Langley apologizes for that oversight. The following is a description of the stack configuration currently being used in the Swanson River workover program: Annular preventer: Shafer 11" x 1500 psi rating with 11" x 3m lower connection. Double -gate: Shafer 11" x 3m Model RS, Flanged. s/n 10D3 -167. Mud cross: 11" x 3m , flanged w/ [2] 3 1/8" x 5m gate valves and [2] 3 1/8" x 5m HCR controlled gate valves. We have the potential to replace the HCR on the kill side with another 3 1/8" 5m gate valve. There is also a spare 11" x 1500 psi annular preventer on location. I hope this sufficiently answers questions raised, but any other inquiries will be answered promptly. Thank you. Doc Holliday Richard 'Doc' Holliday Rig Support 907 - 283 -2520 rholliday @hilcorp.com II 4/27/2012 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Monday, July 26, 2010 11:16 AM To: Myers, Chris S Subject: RE: Swanson River Update #5 Page 1 of 2 Thank you; no problem with recovered fluids going to Class II disposal well. Jim Regg ~ ~ C-Q ~~ S2v ~-.~`~h AOGCC t 333 W.7th Avenue, Suite 100 ._.. Anchorage, AK 99501 `~ `- (~~ ~ S \~ ~ ~ \ 907-793-1236 ~-+ `~ From: Myers, Chris S [mailto:myersc@chevron.com] Sent: Monday, July 26, 2010 11:15 AM To: Regg, James B (DOA) Subject: Re: Swanson River Update #5 Yes, the lines are in field gathering lines Sent from my BlackBerry Wireless Device From: Regg, James B (DOA) <jim.regg@alaska.gov> To: Myers, Chris S Sent: Mon Jul 26 14:00:14 2010 Subject: RE: Swanson River Update #5 ? ~}" Reports indicate recovered liquids were being sent to the fields Class II injection well for disposal. Are the pipelines in question upstream of any custody transfer (non-transportation; gathering lines or production support only)? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Myers, Chris S [mailto:myersc@chevron.com] Sent: Sunday, July 25, 2010 9:11 PM To: tzelenka@blm.gov; claire_caldes@fws.gov; Dewandel, Shannon S (DEC); Russell, Steve A (DEC); Pexton, Scott R (DEC); rees.david@epa.gov; Catalano@circac.org; Regg, James B (DOA) Cc: Myers, Chris S Subject: Swanson River Update #5 To All, This is the fifth situation status report for the Swanson River 21-27 crude release. Please 7/26/2010 Page 1 of 2 Maunder, Thomas E (DOAj From: Myers, Chris S [myersc@chevron.com] Sent: Thursday, July 22, 2010 11:29 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: Swanson River Update #1.xlsx Tom, Jim Wells 21-27 and 21-22 remain shut in until we can excavate the lines and determine the cause of failure. It will be several more days. The two wells make about 1000 bbls of water and 70 bbls of oil per day. Chris S. Myers Operations Superintendent MidContinent/Alaska SBU Chevron North America Exploration and Production Co. 3800 Centerpoint Dr. suite 100 Anchorage, Alaska 99503 Tel 907 263 7654 Fax 907 263 7847 Mobile 907 398 9955 myersc@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, July 22, 2010 11:08 AM To: Myers, Chris S Cc: Regg, James B (DOA) Subject: FW: Swanson River Update #1.xlsx Chris, Thanks for the information. Greg did call me the other night. Jim should be the primary contact here. Greg indicated that 2 wells were SI due to this event. What wells were SI? Thanks, Tom Maunder, PE AOGCC From: Myers, Chris S [mailto:myersc@chevron.com] Sent: Thursday, July 22, 2010 10:37 AM To: Maunder, Thomas E (DOA) Subject: FW: Swanson River Update #1.xlsx Tom, Greg Merle indicated that you wanted to be included on these updates. Here is yesterdays and I will send you the next one later tonight. Give myself or Greg a call if you need anything else. Thanks, Chris S. Myers Operations Superintendent MidContinent/Alaska SBU 7/26/2010 S ill or Release - Information U date Pa e 1 of 2 Status Update No 1 Status Update Date June 21, 2010 at 1800 Next Update: June 22 Initial Release Date and Time July 20, 2010 at 1700 Incident Name Swanson River Field Pad 21-27 Crude Oil Release Responsible Party Union Oil Company of California Location 40 feet from Pad 21-27, Swanson River Field, Kenai, Alaska. Latitude/Longitude Lat: 60 deg 45 minutes 38.4 seconds Long: 150 deg 50 minutes 28.2 seconds Release Controlled and Removed? Release controlled. Ongoing spill response and cleanup. Company Contact Chris Myers @ 907-253-5515 or 907-398-9955 (cell) Onsite Incident Comander Contact: Greg Merle @ 907-283-2543 (office) HES Contact Chris Holden @ 907-263-7364 or 907-223-3117 (cell) Current Weather Conditions: Clear, 60 degrees, light wind Initial Volume Released (Estimate) 15 bbls and unknown square footage Current Volume Released? Approximately 15 bbls as of this re ort eriod Source of Leak Buried crude oil pipeline in ROW. Buried 6' deep. Incident Potential Incident is under control and can be handled with available resources. CISPRI and full ICS resources are not required and have rwt been activated. Short Description of Initial Event A contract crew performing a power pole survey discovered crude oil stained ground along the powerline route near Pad Discovery: 21-27 at Swanson River Field (SRF). No bubbling or indication of active leak was observed. The pipelines in the area were shut in and swept of fluid with gas. The two wells that service the pipelines in the area were shutdown. There was no active leak observed and no gas was observed at the site when the line that was suspected of leaking was evacuated. After sweeping the line with gas, the line was shutin and 132# of gas pressurre was maintained on the line over night. The line was manually depressurized in the early afternoon. There are 3 other pipelines within the area of the leak: 2 natural gas lines and one crude oil line. Other inactive lines are also in the area. Investigation is ongoing to determine the source of the leak. The hydrocarbon leak was within a natural drainage to a culvert (250 yards downgradient) that goes under the road. Sheen was reported along the natural drainage but no sheen was observed on either side of culvert. Sorbent booms are in place at the culvert. Drainage area consists of dense grass and some standing water. Source Controlled? Yes, source has been isolated. Suspect pipeline was isolated, evacuated and depressured. Impacts to Soil and Water? Soil: Yes, impacted off pad soil. Water: No. Evidence to date does not indicate impacts to water bodies or Swanson River Current area impacted by release Impacted Area: Off-pad soil and vegetiation (as of this report period) Square Footage: approximately 2000 SF of surface area. Location: About 40 feet north of [he entrance to 21-27 well pad. Significant Change in Impact Area or No. this is the first report. Volume Since Last Update? Potential Human Health Impact or None based on current information. Community Related Issues? Wildlife or Resource Impacts? No wildlife impacts observed. No adjacent water bodies appear to have been impacted. Discharge is 0.81 miles from Swanson River. Remedial action to Date Source conrolled. Spill area was identified and staked. No soil or water have been excavated to date. Some grass has been cleared to better assess the impacted area. Material Recovered (soil, water)? Soil: No soil removed to date. How much (gallons, yd)? Dewatering: No water has been removed to date Recovered Material Disposal Location Soil: No soil removed to date. Any soil removed will be disposed of at offsRe approved facility (ASR, Emerald). Permission has been received for temporary storage on 21-27 well pad. Water: No water removed to date. Any oil contaminated water will be disposed Class II produced water disposal well at the facility. Agency Contacts: Claire Caldes - USFWS @ 907-262-7021 Email: Claire_Caldes@iws.gov Tom Zelenka -BLM @ 907-267-1469 Email: Tzelenka@blm.gov Sinda Wolfsen -BLM @ 907-267-1441 Email: Swolfsen@blm.gov Scott Pexton -ADEC 907-269-7680 Email: scott.pexton@alaska.gov Shannon DeWandel -ADEC @ (907) 269-7547 Email: shannon.dewandel@alaska.gov Spill or Release -Information Update Page 2 of 2 Status Update No 1 Status Update Date June 21, 2010 at 1800 Initial Release Date and Time July 20, 2010 at 1700 Incident Name Swanson River Field Pad 21.27 Crude Oil Release Key Actions Since Last Reporting Period Action 1: Comments (general): See above Action 2: Removal Action Status: See above Action 3: Leak Identification Status: Leak area will be excavated as soon as contaminated material has been removed. Action 4: Remediation: Surtace Water Sampling: 3rd-Party company is collecting a downgradient water sample to verity that there are no hydrocarbon impacts. Analytical samples will be submitted on rush-turn (48 hours). Sample results will be reported in update as they are received. ~k ~ STATE OF ALASKA ~ ~~ ~ Q~ Z~Q ALAS IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS ~ 1. Operations Abandon Repair Well Plug PerForations Stimulate Other ~ Run 2-7/8" Completion Performed: Alter Casing ^ Pull Tubing ^r Perforate New Pool ^ Waiver ^ Time E~ension ^ ChangeApproved Program ^ Operat. Shutdown^ Perforate ^ Re-ent' Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: . Permit to Drill Number: Name: Develo ment ~ Ex lorato p ^ p ry ^ , 161-010 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ . API Number: 50-133-10155-00 8. roperty Designation (Lease Number): . Well Name and Number: FEDA028406 [Swanson River Facility] S anson Riv Unit (SRU) 21-27 ; Field/Pool(s): ~ ~ v Q ~ ~ ~O~ Sw nson River Field / Hemlock Oil Pool 11. Present Well Condition Summary: ~!'8ska Oil & Gas Cons Commis . Q~ChOCBg@ Total Depth measured~11,142 feet Plugs (measured) N/A feet true vertical 11,142 feet Junk (measured) 10,799 (fish) feet Effective Depth measured 11,000 feet Packer (measured) 10,578 &10,655 feet true vertical 11,000 feet (true vertical) 10,578 &10,655 feet Casing Length Size MD ND Burst Collapse Structural ` / Conductor 40' 20" 40' 40' Surface 2,029' 11-3/4" 2,029' 2,029' Intermediate Production 11,142' 7" 11,142' 11,142' 6,340 psi 3,830 psi Liner Pertoration depth: Measured depth: 10,672'-10,673', 10,676'-10,696', 10,710'-10,773', 10,778'-10,805' True Vertical depth: 10,672'-10,673', 10,676'-10,696', 10,710'-10,773', 10,778'-10,805' 6.4# L-80, 7.9# L-80, 10,621', 10,627'-10,645', 10,621', 10,627'-10,645', Tubing (size, grade, measured and true vertical depth): 2-7/8" 6 N-80 "~-' 10,647'-10,820'MD 10,647'-10,820' ND Baker SB-3 & ,57 ' 10,655'MD Packers and SSSV (type, measured and true vertical depth): Brown HS-16-1 ; 78'&10,655'ND) N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): q~ ~}n {~ N/A ~i~y:"~9~0~~~ iV~,1~ ~' e~' C.L~7 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 10 psi 5 psi Subsequent to operation: 53 225 620 1,480 psi (gaslift) 440 psi 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ^ Development Q Service ^ Daily Report of Well Operations X . Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby ceRify that the foregoing is true and correct to the best of my knowledge. Sundry Number r N/A if C,O. Exempt: 309-309 Contact Stan Porhola 263-7640 Printed Name Timothy C. Brandenburg Title Drilling Manager ~~ ~ ~/ Signature - Phone 276-7600 Date 11/5/09 `~ ~~.~.s ~~ C~I~t ~ Form 10-404 Revised 7/2009 Submit Original Only ~ion ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 21-27 SWANSON RIV UNIT 21-27 FEDA028406 5013310155 QA5325 199.00 :~:' ~,. ~ ~ ~fr« ~ v.~ ~~~ ~ :. ~„: ~,~, Primary Job Type Job Category Objective Actual Start Date Actual End Date Tubing Repair Major Rig 9/7/2009 10/6/2009 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 21-27 501331015500 1610100 Dall ~ ~~ O ratiqna ~.~;<: ~~ ~ ~ .~~x. . ,~: ~~ :~f~: ~~~ ~~ °.. .~ ~ , ~.yk. „ ~,, , . K~ ~ -~ ~ , .. ~ ~ . ~ , ..~ , 916l2009 0(~s00 - 9Pl/ZE1b9 00:00 Operations Summary Mobilize rig from SCU 32-08. R/U Key Energy Rig #3. 9l7/2009 00~00 - 9/8l2tf09 00:00 Operations Summary R/U rig. Working focation to spot rig. Set BPV. N/D Tree. N/U BOPE. Notify BLM and AOGCC Lou Grimaldi of upcoming BOP Test. 9/$12009 00;00 - 9/9/2009 00:00 Operations Summary Test BOPE 250/3000 psi - test OK (1 failure - 3-1/2" ball valve. Remediate & test same - passed). Witnessed onsite by Lou Grimaldi w/ AOGCC. BLM waived witness of BOP test.. Pump 50 bbl 3% KCI down tubing and annulus. R/U APRS wireline. R/U to pull tubing hanger - no joy. RIH w/ 6' 1-9/16" tubing punch. Set down at 10,464' WLM. P/U and correlate from G~M #7 at 7777' RKB. Punch tubing f/10,450' t/10,456' WLM. RIH and set down at 10,464' WLM. POOH. Work to pull tubing hanger. Hanger pulled free. Pull 10K tension. RIH w/ 1-11/16" radial torch and cut tubing at 10,451' WLM. POOH. R/D APRS wireline. UD tubing hanger. POOH w/ 2-7/8" N-80 6.5# EUE 8RD tubing. 91i~~20tl9 flb:00 ~- 911012Q08~ ~~.t~ ~~ ~,F.. ' . ~ - ~ Operations Summary POOH w/ 2-7/8" N-80 6.5# EUE 8RD tubing. UD cut joint = 3.7'. P/U hollow mill fishing BHA. RIH on 3-1/2" Hydril 503 workstring. Tag fish at 10,435' RKB. Swallow 5.5' of fish and latch. Rotate and pick up to release safety joint. Total of 20 right-hand turns as of midnight. 9~10t2~9OQ;EkE~x;~~1~i12005OEI'c00 ; ~ Operations Summary Rotate and pick up to release safety joint. Total of 35 right-hand turns. POOH w/ 4K drag. No fish recovered. Change out grapple and RIH. Rotate and pick up to release safety joint. Total of 45 right-hand turns. POOH. . ,k,: ,... ~ . e, ., . : ~" _ M ~~~~t~oos oo:oo = 9i~ ~rzoos a~~a . . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~~ , n ~~~ ~ Operations Summary POOH. UD overshot - no recovery. M/U new overshot and RIH t/ 10,428' RKB. Work over fish at 10,435' RKB. Jar and overpull up to 30K and made 11 turns (58 total) - no joy. Engage fish w/ 10K overpull and set in slips. R/U slickline. Run 2.0" GR, 1.75" swedge, 1.85" GR, and 2.0" LIB to 10,473' SLM. Showed cut joint fish off center. 9/12l2~09 OOt00 - 9/131Z009 Ot1:00 ,' Operelions Summary Run 2.0" GR, 1.9" swedge and 2.0" LIB to 10,473' SLM. Showed cut joint fish off center. R/D Slickline. POOH. UD overshot - no recovery. M/U OD tubing cutter. RIH to 10,358' RKB. Close 3-1/2" pipe rams. Secure well for the night. Rest crews. 8/13/2009 00:00 - 9/14/2009 00:00 ` Operations Summary Conduct PJSM. SITP = 0 psi. SICP = 0 psi. Monitor well. RIH w/ OD cutter and cut 2-7/8" tubing at 10,496' RKB (2' below collar). POOH. UD OD cutter - full recovery (27' cut joint, 1 full joint, 2' cut joint). M/U overshot. RNi to fish and work over to 10,507' RKB. Unable to latch fish. R/U slickline. Run 1.83" GR and work to 10,604' SLM. P/U to 10,400' SLM. R/U to circ down tubing. 9/14f2009 ~1:00 - 9/15f200~ 00:00 ~ ~ ~ ~„ , ~ ~ ~ ~ Operations Summary Pump 60 bbl 3% KCI down tubing. RIH w/ 1.83" GR and tag at 10,604' SLM. POOH. R/U E-line. RIH w/ CCL and correlate GLM #8 at 10,527' WLM. POOH. RIH w/ 1.5" GR and tag at 10,609 SLM. POOH. RIH and punch tubing f/10,553' t/10,559' WLM. POOH. RIH w/ 1-11/16" radial torch and cut tubing at 10,556' WLM. Wireline stuck. Overpull tubing 12K and tbg pulled free. P/U tbg 15' above cut. Unable to free stuck wireline. Work wireline and pulled free. POOH. Left rope socket and cutter in hole. RIH w/ 1-3/8" JDC to 10,584' SLM. Fish rope socket - no recovery (4 runs). 9f1~512Q09 00:00 - 9N8120f~ Ot~:O(f ` ~ ` ~ ~ _ .~. ~ . . , Operations Summary RIH w 1-7/16" overshot ko 10,588' SLM. Pump 38 bbl 3% KCI down tubing w/ returns at 25 bbl. POOH. Left overshot in hole. RIH w/ 2.0" JDC retreiving tool to 10,589' SLM. POOH - no recovery (2 runs). Pump 90 bbl 3% KCI down tubing. Reverse circ 140 bbl taking returns up tubing - no scale/solids in ' returns. RIH w/ 1.75" pump bailer, 2.0" JU retreving tool, and 1.80" LIB in multiple runs to 10,582' SLM. Recovered scale and metal cuttings. Unable to recover fish. Impression block showing cut tubing joint and possibly top of overshot. Notify BLM and AOGCC of upcoming BOP Test. , 9~1~t`2~~ o~:o~ ~. ;'~t~ooa o~:oo ~ ~; ~, n, ~A r~~. Operations Summary RIH w/ 2.0" JUC retreiving tool to 10,580' SLM - no recovery (2 runs). R/D slickline. POOH w/ overshot on 3-1/2" workstring - no recovery, GLM #8 left in hole. R/U and test BOPE to 250/3000 psi. Witness waived by BLM & Jeff Jones w/ AOGCC. Secure well for the night. Rest crews. S ~ ~7f2bb9 OO:b~ - 8/18/2009 Od:00: ~ ~ s,:~ ~„-. . ~ _. ~.,, ; ~.: . ~; _ „ ~~ ~ Operations Summary P/U double overshot and RIH to 10,496' RKB. Latch fish. O/P to 50k. Rotate 8 turns to the right. Fish came free w/ 17k drag. POOH. UD fish. Recovered 29' cut tbg, GLM #8, 1 full tbg jt, and box end of CC safety joint. Slickline overshot recovered inside tubing. Noted tubing punch holes, however no radial torch cut on tubing. R/U slickline. Ran 5.75" LIB and 5.875" overshot, hanging up shallow. POOH. Secure well. Rest crews. r ~ ~Chevron ~ Chevron - Alaska ~ Daity Operations Summary Well Name Legal Well Nama Lsase Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 21-27 SWANSON RIV UNIT 21-27 FEDA028406 5013310155 QA5325 199.00 ~ ~ ~;~4 ~ ~` ~ ` ~ :, . ~ . :~ ~ w. ~~ ,: : ~ ~ ,. <.~ ~ . 9l'!$1' ~008 QtktO(~ = 9119f2009 OO:OQ ~ ~ ~ ~~ ; ~ ~ ~ Operations Summary P/U 1-7/16" grapple and RIH on 3-1/2" workstring. Latch fish at 10,557' RKB. Pull free at 4k overpull. Circ well. Monitor for losses - no losses. Secure well. Rest crews. 9/19t2009 00:00 - 8/20/200$ 00:00 Operations Summary POOH. Recovered fuil fish - radial torch and rope socket. P/U 6" rotary shoe and 5-3/4" washpipe and RIH on 3-1/2" workstring to 10,556' RKB. Wash f/ 10,556' t/10,582'. Saw small amount of scale and metal fragments on bottoms up. R/U slickline. ~ t . . . .,. ~, ~, .< . 9I201200~ ttb:00 - 9/2i12009 00.00 `- ° . ~~ ~ ~ ~ ~~ ~ ~~ Operations Summary RIH w/ 1.75" bailer and 1.75" magnet to 10,605' SLM (4 runs). Recovered metal pieces and shavings. RIH w/ 1.75" star bit, 1.75" bailer and 1.90" swedge, work to 10,612' SLM (5 runs). R/D slickline. POOH w/ workstring and UD washpipe. P/U 5-7/8" OD cutter. Secure well. Rest crews. ,b. .r 9l2'1/2008 OQ~QQ -~9f2212009 00:00 ~ ~ ~ ~ Operetions Summary RIH w/ OD cutter. Move over fish and make OD cut on 2-7/8" pup at 10,572' RKB. POOH. Recovered pin-end CC safety joint and tbe cut - full recovery. Secure well. Rest crews. 8~21200~~t1;00~-9/23t~f~09OO:tiO~~~:: ~ ~ ' ~ ~ ~~,~ ~ ~. ~ ~ . ~ Operations Summary P/U double overshot BHA. Washover fish at 10,572' RKB. Work fish w/ 50K overpull and 80 turns to the right. Unable to move up hole, packer able to move down. Work packer to 10,609' RKB. Unable to rotate or move packer. R/U E-line. RIH w/ 1" CCL. 8123f2009 00:00 . 9124/200~ 00:00 µ Operations Summary RIH w/ 1" CCL. Set down at 10,612' WLM (3' below top of fish). POOH. Attempt to rotate overshot off fish - no joy. RIH w/ 1-9/16" tbg punch and punch 10,592'-10,598' WLM. POOH. RIH w/ 1-11/16" radial torch and cut 2-7/8" PH-6 joint at 10,592' WLM. POOH. Recovered workstring, new top of fish at 10,588' RKB, leaving 25.29' overshot fish. R/U to test BOPE. 9t24/2QQ~~~:00 - 9/~t2009 OQ.O~C. ~ ~ ~ ~ , Operations Summary Test BOPE to 250/3000 psi - test OK. Witness waived by BLM & AOGCC Jim Regg. P/U cleanout assembly w/ 1-1/4" CS-Hydril (1.660" OD). RIH to 10,605' RKB. Reverse circ at 3 bpm and wash down f/10,605' t/10,730' RKB. P/U to 10,595' RKB. Secure well. Rest crews. 91~3i12009 OQ:t~O~ - 8/26l200ff 00:00 ~ ~ ~ ~` " ~ _~ ; ~ ~ ~ ~ ~ _ ~ ~ ~ ~ Operations Summary ~ RIH fl10,595' U10,699'. Reverse circ and wash down at 5.0 bpm f/10,699' to 70,756'. Established communication thru tubing punch holes below packer. Monitor well. POOH. UD cleanout BHA. P/U overshot BHA. RIH t/545'. Secure well. Rest crews. 9/2i#f2Q08 OO:OQ'~ 8/27/20(F~ ~tizQO '~° Operations Summary RIH w/ overshot BHA t! top of fish. Latch on fish and attempt to free w/ 60K overpull - no joy. R/U E-line. RIH w/21' of 1-9/16" tbg punch and tag up at 10,629' WLM. POOH. UD 21' tbg punch and P/U 6.75' tbg punch and tag up at 10,629' WLM. POOH. R/D E-line. R/U slickline. $f2T12009 OQ:00 - 9/28/200~ 00:00 ~ ~ ~ s' ~ . ~ ` .,~ ~ `~: : ~ Operations Summary RIH w/ slickline for 5 runs to 10,662' SLM - no recovery. Unable to work passed. R/D slickline. Work overshot for 60K overpull - no joy. Release overshot, POOH. UD overshot. P/U cleanout assembly w/ 1-1/4" CS-Hydril (1.660" OD) t/726'. Secure well. Rest crews. 8l2$/2009 ~il;bik- 9129/20Q9 00:00 " `' . , p Operations Summary P/U cleanout assembly w/ 1-1/4" CS-Hydril (1.660" OD). RIH to 10,572' RKB. Circ btms up. Work to enter fish (top of 8' pup above packer). Unable to work down. POOH t/ 6605' RKB. Secure well. Rest crews. 9/29t~,~109 OO:OQ - 9I30I2009 04:00 ~ ~ ~`„ ~~ ~ ~ ~ ::,~..~r ~ , Operetions Summary POOH f/ 6605' RKB. UD cleanout BHA. P/U tapered mill and motor BHA. RIH t/10,596'. Secure well. Rest crews. ,., . ~ .,. 9130/ t~~00t00~~-1Qt11~008 OO:QO °~"•' '~' ~ :~ :, ~.., .., ~ Operations Summary RIH tapered mill and motor U10,606' and mill down top of fish. RIH and tag obstruction at 10,627'. Unable to work below obstruction. P/U to 10,336'. Pressure up to test casing. Well went on vacuum at 1500 psi. Pump 60 bbl 3% KCI with well still on vacuum. RIH and tag obstruction at 10,627'. Spud on obstruction and worked to 10,629'. POOH t/ 10,400'. Secure well. Rest crews. Notify BLM and AOGCC of upcoming BOP Test. 10/1/2009 00:00 -10/2/2009 OOt00 ~' '`~~ Operetions Summary Circ 280 bbl 3% KCI. Well still on vacuum. POOH. UD tapered mill and motor. R/U and test BOPE to 250/3000 psi - test OK. BLM & AOGCC John Crisp waived witness. Secure well. Rest crews. ~~/2009 QO:~:~'tOf3/2009 p:00 ~ ;>,~ r ~"` _ Operations Summary Circ 150 bbl 3% KCI. Well still on vacuum. R/U to run 2-7/8" completion w/ overshot. RIH t/6600'. Secure well. Rest crews. / / ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (k) Water Depth (ft) SRU 21-27 SWANSON RIV UNIT 21-27 FEDA028406 5013310155 QA5325 199.00 Da '~t~ ~. ~ ~H. ~~ ~~a ~ ~ > ~:~' ~ ,.. . ,~ ~. _ . ~; . ~ ~. ,,: ~. . : 10t~/2009 Qp;00 -1014/2009 0~t10 `' Operations Summary RIH w/ 2-7/8" completion. Work overshot over top of fish at 10,611' (23' deeper than previous depth of 10,588'). Stack out 10K on fish and no movement. Space out to set packer. RIH w/ 6' 1-9/16" tubing punch and tag up at 10,645' WLM (bottom of Brown packer). Pump 3% KCI down tubing to clear obstruction. Well still on vacuum. Tag 10,645' WLM again. POOH w/ tubing punch. RIH w/ PX plug on slickline and set in X nipple at 10,570' SLM. POOH. Pressure up to 4000 psi and set SB-3 packer at 10,578'. P/U 30k over string weight and pull seal assembly out of PBR. Fill annulus w/ 3% KCI. Space out seal assembly w/ locator 4.5' above PBR. Land hanger. Test annulus to 2500 psi for 30 min - test OK. Secure well. Rest crews. 10~4/2009 ~b:OQ -1015t~009 00:00 ~ ~ ~ ~~ ~ ~ ~ ` ~ :~ ~; ~ ~ ~~ ~` . ; ~ Operations Summary Set TWC. N/D BOPE. N/U Tree and test to 250/5000 psi - test OK. Set VR plugs and change out annulus valves. Test new valves to 250/5000 psi - test . . Move rig to SCU 33-33. ; : x ~, O/5/2 Q9 OOtOb -10t61200& O~tOQ , : , " ,_ ; per ons Summary R/U slickline. Pressure test lubricator 250psi low/2500psi high. Change out dummy valves to live valves in GLM #1 -#4. Pull prong and plug fron X-Nipple. R/D slickline. Turn well over to production. evro SRU 21-27 -" ° Actual Wellbore Schematic ' ' - -' ' '' ' ~ - . ~ ~ ~• RKB =199 G L = 784' ~^@ ~t•y~ Radi z-~~e OD C z-ne CASING AND TUB[NG DETAIL SIZE WT GRADE CONN ID TOP BTht. 20" - - - 40' 11-3/4" 47 - 8RD 11.00 Surface 2,029' 7" 29 P-110 BTC 6.184 Surface 160' 7" 26 N-80 BTC 6.276 160' 1091' 7" 23 N-80 BTC 6366 1091' 4783' 7" 26 N-80 BTC 6.276 4783' 6583' T' 29 P-110 BTC 6.184 6583' 8398' 7" 29 P-ll0 8RD 6.184 8398' l1,142' Tubing 2-7/8" 6.4 L-80 IBT(SCC) 2.441 Surface 1Q621' 2-7/8" 79 L-80 PH-6 2323 10,62T 10,645' 2-7/8" 6.5 N-80 EUE 8RD 2.441 10,64T IQ820' NO. lleoth ID JEWELRY DETAIL (NEW) OD Item 1 4382' 2.441 4.750 SFO-1 GLM w/1/4" valve [installed 10/OS/09~ 2 6513' 2.441 4.750 SFO-1 GLM w/1/4" valve [installed 10/OS/09] 3 8684' 2.441 4.750 SFO-1 GLM w/1/4" valve [installed l0/OS/09~ 4 10,525' 2.441 4.750 SFO-1 GLM w/3/8" valve [installed l0/05/09~ 5 ]0,559' 2.410 4.630 Tubing locator ~v/ 12' of seals (spaced 4.5' above PE3R) 6 10,564' 3.250 4.300 l2' PBR 7 10,577' 2.425 4.630 E-Anchor 8 1Q578' 2.441 5.680 Baker 2-7/8"x7'' SE3-3 Packer 9 1Q583' 2.441 2.875 XO from packer to 2-7/8" tubing 10 10,619' 2.313 2.875 "X" Nipple (2.313" Min ID) 11 10,62Y 2.438 4.250 Overshot WLEG (Non-sealing) ti0. Depth ID JEWELRY DETAIL (LEFT IN HOLE) OD Item 12 10,62T 2.323 2.875 Cut joint (2-7/8" 7.9# PH-6 tubing) (2.229" Drift) 13 1Q645' 2.250 5.750 Dual Bowen 150 Overshots (Sealing) 14 10,647' 2.441 3.500 Cut joint (2-7/8" 6.5# 8RD tubing) (7.78' long) 15 1Q655' 2.500 5.875 Brown 2-7/8"x7" HS-16-1 Packer (Stuck) 16 10,724' 2.313 3.500 Camco "D" Nipple 17 1Q820' - - Venturi Shce *ALL JEWELRY HAS MOVED 60' DOWNHOLE* ('IIRRF'NT PFRFOR,1'1'I(1N nATA fMDI Tibe ,o,r9 ~~ , ~~~ ~ Zone To Btm DATE S f Comments H1 10,672' 1Q673' S-2-61 5 2-1/8" WSO #1 H1 10,676' 10,696' S-4-61 4 2-1/8" ca sule H2/3 10,710' 10,773' S-4-61 4 2-1/8" ca sule H4/5 1Q778' 10,805' S-4-61 4 2-I/8" ca sule 7" Cement Bond Lo~ 10,195' - 10,280' - Good 10.365' - 10,432' - Fair 10,575' - 10,604' - Good 10,675' - 10,710' - Fair TD=11,142' PBTD=11,000' Directional Data: ma7c hole angle = 2.25° at 2035' MD SRU 21-27 Actual Well Schematic 10-05-09 doc Updated bv STP 10-06-09 • • ~ ~~ ~ ~ ' ~' ~ `~ ~ °, ~~ ` ~ ~ `~ ~ ~~ ~ ~ ~ ~ ~~, ~~ ~ ~~ ~~ { , s"~~, ~ ~~ ~ ~ ~' ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR % ~`~~ ~ ~ ~. ~.~ ~ ~~'~ ~~ ~~~ ~ ~-7~~ ~I~ tu~L Vrv*7 333 W. 7th AVENUE, SUITE 100 COI~TSER~TA'1`IOl~T COMl-IISSI011T ~ ANCHORAGE, ALASKA 99501-353 PHONE (907) 279-1433 r FAX (907) 276-7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 9 Re: Swanson River Field, Hemlock Oil Pool, Swanson River Unit (SRU) 21-27 ~ ~~D ,~~ Sundry Number: 309-309 ~ 4~~~~ ; ,~~3~";'~ Dear Mr. Brandenberg: T Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~,°l Daniel T. Seamount, Jr. Chair DATED this ~ day of September 2009 Encl. ~ '"'~' ~ ~ ~ r,. ~ ~ '~,~: ~ ~i~~ D 1 q',~ STATE OF ALASKA `.._~' "~ ,~ ~;~~~ f.~ O~I / ALAS~IL AND GAS CONSERVATION COMMI~N i~lfi/~ G~'~ APPLICATION FOR SUNDRY APPROVALS ~= ~~~~~ '` ~~ q~~'~~'~''Op 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ PerForate ^ Waiver ^ Other ^~ Alter casing^ Repair well [] Plug Perforations ^ Stimulate ^ Time Extension ^ Run 2-7/8" Change approved program^ Pull Tubing Q- Perforate New Pool ^ Re-enter Suspended Well ^ Completion 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number. Union Oil Company of California Development ~ Exploratory ~ 161-010 - 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10155-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Weil Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ Swanson Riv Unit (SRU) 21-27 ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028406 [Swanson River Facility] 15' ~ Swanson River Field/Hemlock Oil Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,142 11,142 11,000 11,000 N/A 10,379' (fish in tubing) Casing Length Size MD ND Burst Collapse Structural Conductor 40' 20" 40' 40' Surface 2,029' 113/4" 2,029' 2,029' psi psi Intermediate Production 11,142' 7" 11,142' 11,142' psi psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# N-80 10,760 Packers and SSSV Type: Packers and SSSV MD (ft): Brown HS-16-1 Packer / N/A 10,595' / N/A ~ 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP S h Q Exploratory ^ Development Q' Service ^ 15. Estimated Date for /8 009 16. Well Status after proposed work: Commencing Operations: Oil Q- Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola 263-7640 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ \ Phone 276-7600 Date 9/2/2009 / "~~ ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~O~ ,~~ Plug Integrity ^ BOP Test ~ Mechanicai Integrity Test ^ Location Clearance ^ Other: T~CS"l RO ~ E '~'p 3Q00 ~~~,, . ~er Zo ~}'l~c 25 . 2.Y'S t~~ ~ a.l~'ev u.u.f 'e ~~ P~ i s a, t ro v e.c~ . ~~ Subsequent Form Required: ( Q - ~4 • ~ ~. '' APPROVED BY ~ 3 ~ Approved by: ~" COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~-- ,':_' °~ ~ ~~Q~ Submit in Duplicate ~-~*-. . Chevron ' • • Swanson River Unit ~ Well # SRU 21-27 ~ 9/2/09 OBJECTIVE: • Pull existing & rerun a new 2-7/8" completion. PROCEDURE SUMMARY: 1 [PRE-RIG] R/U wireline and run CCL to (+/-) 10,555' to confirm location of GLM#8. 2 MI/RU Key Energy Rig #3. 3 N/D Tree. N/LT and Test BOPE 250/3000 psi. ~ 4 Pump 3% KCl down tubing and annulus for well kill. Flow check well 5 R/U and pull tubing in tension. 6 R/iJ wireline, RIH, and cut tubing at (+/-) 10,555'. 7 POOH w/ 2-7/8" tubing from (+/-) 10,555'. 8 Wark over cut tubing stub at (+/-) 10,555' w/ tubing overshot BHA w/ hollow mill control. Rotate to recover box end of safety joint. Contingency [If unable to recover safety joint.] A RIH w/ washpipe & reversing basket and wash over tubing down to packer at 10,595'. POOH. B RIH w/ tubing overshot BHA. C Work over cut tubing stub at (+/-) 10,555'. Rotate to recover box end of safety joint. 9 POOH. L/D overshot and tubing stub. 10 M/U tubing overshot BHA. 11 RIH. Work over pin end of safety joint at 10,584'. 12 RIH. Equalize & disengage packer. POOH. L/D packer. ~ 13 RIH w/ 5-7/8" bit and string mill to top of squeeze perfs at (+/-) 10,672'. POOH. 14 ~H w/ new 2-7/8" 6.4# L-80 IBT tubing & SB-3 packer, with dummy valves in GLM's. Set same w/ packer at ~ (+/-) 10,559' and tubing tail at (+/-) 10,642'. 15 Fill annulus w/ 3% KCI. 16 R/U and pressure test annulus to 2500 psi for 30 min. R/D test equipment. 17 Land out, N/D BOP, N/U Tree. 18 Turn well over to production. SRU 21-27 REVISED BY: CVK 9/2/09 SRU 21-27 Wellbore Schemati RKB = 199 G L = 1&t' m^ft 11-31~ CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" - - - 40' ll-3/4" 47 - 8RD ll.00 Surface 2,029' 7" 29 P-110 BTC 6.184 Surface 160' T' 26 N-80 BTC 6.276 160' 1091' 7" 23 N-80 BTC 6366 1091' 4783' 7" 26 N-80 BTC 6.276 4783' 6583' 7" 29 P-110 BTC 6.184 6583' 8398' 7" 29 P-110 8RD b.184 8398' 11,142' Tubing 2-7/8" 6.5 N-80 EUE 8RD 2.441 Surface 10,760' NO. Deoth ID JEWELRY DETAIL OD Item 1 1445' Camco MM w/RD valve set 2 2912' Camco MM w/RD valve set 3 4219' Camco MM w/RD Orifice w- 5/16" port set 4 5272' Camco MM w/Dummy set 5 6233' Camco MM w/Dummy set 6 7064' Camco MM w/Dummy set 7 7777' Camco MM w/Dummy set 8 10,540' Camco MM w/CEV valve set 9 10.584' 2.4375 3.6875 Brown CC Safety Joint 10 10,595'- Brown 2-7/8"x7" HS-16-1 Packer (set Dec-62') 11 10,664' Camco "D" Nipple 12 10,760' Venturi Shce ('IIRRF'NT PFRFORATI(1N nATA lMill r,be 0,73 ci , ~~~ ~ TD=11,142' PBTD=11,000' Directional Data: ma~c hole angle = 2.25° at 2035' MD Zone "1'o Btm Dr1TE S f Comments H1 10,672' 10,673' S-2-61 5 2-1/8" WSO #1 H1 10,676' 10,696' S-4-61 4 2-1/8" ca sule H2/3 10,710' 10,773' S-4-61 4 2-1/8" ca sule H4/5 10,778' 10,805' S-4-61 4 2-1/8" ca sule 7" Cement Bond Log 10,195' - 10,280' - Good ~ 10.365' - 10,432' - Fair ' 10,575' - 10,604' - Good 10,675' - 10,710' - Fair ' Slickline Runs 7/3/09 10,355' - Ran 2.13" GR 10,557' - Ran 1.85" GR 9,603' - Ran 2.23" GR 10,557' - Ran 2.0" GR 10,555' - Ran 1.75" Bailer SRU 21-27 Actual Well Schematic 6-26-09 doc Updated bv STP 9-02-09 SRU 21-27 Proposed Wellbore Schematic RKB =199 G L = 784' to° ~ I 1-y~ CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP 67'M1l. 20° - - - 40' 11-3/4" 47 - 8RD 11.00 Surface 2,029' 7" 29 P-110 BTC 6.184 Surface 160' 7" 26 N-80 BTC 6.276 160' 1091' 7" 23 N-80 BTC 6366 1091' 4783' 7" 26 N-80 BTC 6276 4783' 6583' 7° 29 P-110 BTC 6.184 6583' 8398' 7" 29 P-110 8RD 6.184 8398' l1,142' Tubing 2-7/8" 6.4 L-80 IB'C(SCC) 2.441 Surface 10,642' NO. Deoth ID JEWELRY DETAIL OD Item 1 a351' SFO-1 G1,~1 2 6d89' SFO-1 GL~I 3 8658' SFO-1 GL~I 4 10,486' SFO-1 GI,~I 5 10,53T 10' Sealborc I~:~icn,iun 6 10,557' XO from 2-7/8" pup joint to packcr 7 10,559' Baker 2-7/8"z7" SB-3 Packer ~ 8 10,564' XO from packcr tu 2-7/8" tubing 9 10,605' "Y" Nipplc 10 I O.G-l2' ~~ I.H:G ('1'RRF'VT PFRF(1RAT1(lV DATA (~1n1 ~~~ ~ TD=11,142' PBTD=11,000' D~rectional Data: ma~c hole angle = 2.25° at 2035' MD Zone To Btm DA"CE S f Comments H1 10,672' 1Q673' S-2-61 5 2-1/8" WSO #1 H1 10,676' 10,696' S-4-61 4 2-1/8" ca sule H2/3 10,710' 10,773' S-4-61 4 2-1/8" ca sule H4/5 10,778' 1Q805' S-4-6] 4 2-1/8" ca sule 7" Cement Bond Log 10,195' - 10,280' - Good 10.365' - 10,432' - Fair 10,575' - 10,604' - Good 10,675' - 10,710' - Fair SRU 21-27 Proaosed Well Schematic 9-02-09.doc Updated bv STP 9-02-09 Chtwron ~ ~ ~ BOP Diagram SRU 21-27 Workover ~ 9/2/2009 ~Annular preventer, Shaffer, I 7 1/16 5M Flanged 2.58' I haffer Chasovoy 7 1/16 1.00' stdd X 7 1~M stdd ~ ~ affer Chasovoy 7 1/16 stdd X 7~ 5M stdd 1.75' Kill line 2 1/16 1.83' o 0 °o °o Unibolt Pipe Ram ' 7.16' Pipe Ram ' ! ~~~ Blind Ram ' _~ ~~ Mud Cross, 7 1/16 5M FE X 7 1/16 5M FE w/ 2 1/16 5M X 3 1/8 5M EFO Choke line 2 1/16 5M HCR i Unibolt ~ DSA 31/85MX21/165M ~ . Chevron Timothy C Brandenburg Union Oil Company of California ~ Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 ~ Tel 907 263 7657 Fax 907 263 7884 Email brand~nburgt@chevron.com ~ Y : ~ ~_ September 2, 2009 ~~~ ~~ ~ ' ~~ ~~~~~~ ~ ~~~ ~`: ~ ~ ~_ ~,~ (' ~ ~t ~: 2 ~,s~. Commissioner y= p, ~ ~ ,> ~ t r.~?~iS','~ .. .i ~l~i Alaska Oil & Gas Conservation Commission : 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Swanson River Workover Program Variance Request for SRU 21-27 Dear Commissioner, _ UOCC is requesting a variance of 20 AAC 25.285 (c) (9) and (10 or well service work in the Swanson River Field, for SCU 33-33. UOCC is currently performing well intervention work with a"well servicing unit" provided ~~ by Key Energy. Key Energy mobilized the workover unit here from the Rocky Mountain area. After reviewing the BOPE rig up and equipment as used in UOCC's last Swanson River workover campaign in 2004, we feel that the proposed system is fit for purpose in well control capabilities and mobility to other BOPE configurations for this well service work. This variance request was granted for the KGSF #1 workover on Sundry Number 309-221, and was successfully utilized on this well intervention. As in this same configuration successfully used in 2004, UOCC is asking for a variance of the kill line and choke line configuration and the choke manifold equipment ' requirements. We consider the application of this and all BOP configurations to be a well bore specific concern and do not intend or desire to consider this as an area wide or unilaterally applied configuration. UOCC appreciates your consideration of this proposal and looks forward to discussing any questions with the proposed configuration as needed. Attached is a brief description of the well to be worked on, and the proposed BOP configuration and schematic. Please let us know if we can provide any further information by contacting myself at 263- 7657 or Evan Harness at 263-7932. Sincerely, ~/~-..~ • Timothy C. Brandenburg ~~ Drilling Manager Attachments: Summary of Swanson River Workover Program, BOP diagram, Choke diagram Union Oil Company of California / A Chevron Company Chevron • ~ ~ ~ Summarv of Kev Enerqv Riq #3 Specifics SRU 21-27 Workover The SRU 21-27 workover is to pull the existing completion, fish and cleanout to the base of the Hemlock (or as deep as possible) and run a new completion. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Confiquration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft- 9/16" sand line. Derrick The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Shaffer ' Single gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram % Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram and blind ram ~ Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 140 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Fourteen 11 gallon accumulators with four 11 Gallon Nitrogen Bottles for backup. 210 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Key Energy Rig #3 Specs (SRU 21-27).doc 7/27/09 Chevron ~ ~ ~ ~ Kill Line Valves The kiii line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-flex hose with a Unibolt/Hub-flanged connectors. Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically, operated HCR valve that is attached to the mud cross with co-flex hose with a Unibolt/Hub-flanged connectors. Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SRU 21-27).doc 7/27/09 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook inlet/New Ventures Engineering July 25, 1988 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Sundry Notice for SRU 21-27 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to acidize Well SRU 21-27. We propose to acidize SRU 21-27 with a diverted mud acid treatment in order to increase the well's productivity. The treatment will consist of 9,000 gallons of mud acid and a 3,500 gal. overflush. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Wes Peirce at 263-4228. Sincerely, T. Wellman Interim Manager TW:DAP:0004 ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany STATE OF ALASKA ALASI~A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] -Perforate [] Other [] Name of Operator ARCO Alaska,. Inc. Address ' Post Office Box 100360 Anchora~le, AK 99510 Location of well at surface 630' FNL, 2,195' FWL, Sec. 27, T8N, R9W, SB&M At top of productive interval 630' FNL, 2,195' FWL, Sec. 27, T8N, R9W, SB&M At effective depth 630' FNL, 2,.195' FWL, Sec. 27, T8N, Rgw, SB&M At total depth 630' FNL, 2,195' FWL, Sec. 27~ T8N~ Rgww SB&M 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Datum elevation (DF or KB) 199' KB 6. Unit or Property name Swanson River Un 7. Well number SRU 21-27 8. Permit number 9. APl number 50-- 10. Pool Swanson River - Hemlock 11,142 feet 11,142 feet Casing Length Structural 40' Surface 2,029 ' Production Perforation depth: Measured: 10,676' - 10,696'; 11,000 feet feet 11,000 Size 20" 11-3/4" 11,142' 7" True Vertical: 10,676' - 10,696' Tubing' (size, grade and measured depth) 2-7/8" EUE, N-80, 10,760' MD Packers and SSSV (type and measured depth) Plugs (measured) 12.Attachments Junk (measured) Cemented feet to surface 1,350 SX Measured depth True Vertical depth 40' MD 40' TV[ 2,200 SX 2,029' MD 2,029' TVI 11,142' MD 10,710' - 10,773'; 10,778' - 10,805' ; 10,710' - 10,773'; 10,778' - 10,80.5J..~. 11,142' TVI Detailed operations program Description summary of proposal 13. Estimated date for commencing operation August, 1988 14. If proposal was verbally approved Subsequent Work ~epo~e~ on ~'orm No ....... Dated Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ b(2~~-~_..~ Title Cook I n let Inter i m Manager Commission Use Only Date Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returne?~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate SRU 21-27 ACid Stimulation Procedure Confirm Sundry Notice approval through Engineering before proceeding with procedure. 1. Safety Meeting with all personnel involved in the treatment. 2. Titrate acid on location to ensure proper acid concentration: . . . . 10. 11. A. ARCO personnel should witness on site titration. B. Follow the attached procedure for mud acid titration. Check pumps, tanks, mixers etc. for cleanliness. MIRU Dowell. Pressure test lines to 4,000 psi. Establish injection rate with 20 Bbls 2% NH4CI water + 1% L53W. Do not exceed 3,500 psi surface injection pressure. NOTE: .When tubing has a full liquid column, do not exceed 3,500 psi surface injecti.onpressure. Surface pressures should be monitored carefully because injection pressure may nse as the diverter contacts the perforations. Pump 1,500 gals. of 7-1/2% HC1 + 0.4% A250 + 20 lbs./I,000' gals. L58 + 0.5% F75N + 100g/I,000 gals. L41 Pump 3'000 gals. of 6%. HC1 - 1.5% I-IF + 0.4% A250 + 20 lbs./I,000 gals. L58 + 0.5% W35 + 100g/1,{X}0 gals. L41 + 5% F75N. pump 1,000 gals. of 2% NH4C1 with 1 gal./I,000 gal. J237 (OSR Diverting Agent). Repeat steps 5 and 6. Pump 3,500 gals. of 2% NIt4CI + 10% U66 + 1% L53W (Clay Stabilizer). Displace tubing with gas lift gas. Return well to production. (NOTE: Acid may not be completely spent when it is produced to the surface, Soda ash Should be used to neulxalize any unspent acid.) ARCO Alaska I~. I$ a ~ul~idlaty o~ Atlantio Richfiedd Company ARgB-OOO*I-A AnCh · UNITED STATES DEPARTMENT OF THE INTERIOR u~}.r_ g~aBSOB. ~ve~ g~ - GEOLOGICAL Su~YEY LESSEE'S ~oNTHLY REPORT OF 'oPER~VrlONS 8~a~e ................. report°f''p''r°t~'~:''s'''nd' ......... ~.0 swanson ~ver U~t .I. mon~ °f ...... .... ~ a~a .. . .- (.:om.p, , · ., :. , ~ ~0~ , ID for t.~c " - Bo~ /'v~' - -- ._ .. , i 'C. ~.~CH~--"-~nden~---5 .~e u. e . ~ ) p. O. ...... . ,q~,mc, - ~ erx~ . - .......... " w~--~ ...... ~~ ........- .... . .... .---~~ ~ ~:I'. r~. , ~ } ' with ~l~m ,---; 7/8. tubi~. ~ BO~o ~led ~q~pO~ wi~h packer ~6 7 'State t 1 ~ - ,,~. c.~Wo Perry / ' Richfiex~' ~ ~R. Ritteri · 'RECEIVE D" ~ Alaska Dept. ~f Na,urm Ne~curce~ M aa. [~. of gas sold; runs or sales o[ air; ................. ~'nn" where aPPlieab!°') .................... - month. (Writ~ st,du~ ~ ...... There were ................... -~'~ of ~asoline during t.~_e regardless of the supervisor. ,- .... _ .......... runs qr [",~L o~h e~endar moan,, ...... ~ ~geport on tins term ,s reqmred mr ~,, onth, unless other',vise duplicate with the m~perVisor by the Otb o~ the sucucediUg m Form 9-a~9 0angry 19~) }-'orm P- 7 SUBMIT IN DUx .3ATE* STATE OF ALASKA (Se,, other st ruct ions on reverse side; OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* _ .... , la. TYPE OF W~.LL: oxl, ~s W ELI. W ELL DR v Other b. TYPE OF COMPLE~ON: NEW ~ WOnK ~ DEEP- ~ PLUG ~ w El,I, OV ER E N BACK ~ESVR. ()thor ~ 2 N&ME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOC^Vms OF WELL (Report location clearly and in accordance with a.y State requirements)* At surface 5. API NU2VI_EJtJCAL CODE 6. LEASE DESIGNATION A2qD SERIAL NO. 7.IF INDIA_N, ALLOTTEE OR TRIBE NAiVIE 8.UNIT,FA/llVI OR LE~kSENAME 9.WELL NO. 10. FIELD AND POOL, OR WILDCA. T 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) At top prod. interval reported below At total depth 12. PEWI3/IIT NO, HOW MANY* ROTARY TOOLS 22.PI%ODUCING !NTERVALiS), OF THIS CO.MpI-~TION--TOP, BOTTOM, NAME (MD AND R'r, GR, ~'FC)*{17. E/.2EV. CASINGHEAD I INTERVALS DRILLED BY CABI.E T00I,S 23. WAS DIRECTIONAL SURVEY MADE l 24. T%~PE ELECTRIC AND OTHIKI% LOGS RUN CASrNG RECORD (Report .~11 strings set in well) ;to fo : , , - · 't , , 2o. ~NE~ B~:C0t~D 2,. 28 PERFORATIO1NS OPKN~ TO PRODUC~iOI%I (interval,size' and number) ' iii iiiii ii i i i i ii 30. PRODUCTION CIZiMLNTING RECOF~D A. NIOUNT PULLED SCiiEEN (MD) SIZE DEPTH SE/' (MD) 29. ACID, Si:OT, FiIAC~i URE, Cw-".IENT SQUE~Zi~, ETC. ii TUMS0 a~CO~ ~ PACKER SET (MD) DEPT'Ii 1NTEIqV.~L (MD) AM©UN£ A_ND Ii!ND OF MA'IEi~IAL USF_,D DATE FIRST PI%ODUCTION I PI%ODUCT1ON MILIHO'D (Flowir~g, gas lifiL pumping--size and type of pump) .: DATE OF TIgST, I~OURS TESTED ' [CI-tOXE SiZE [PP. OD'N FOR OI~BDL. , FLOW, ~BING CAS~G PRESSURE CALC~T~ OI~BBL. 31. ~SPOS~T~ON Or Cas (Sol'~, u~ed for tool, yen'ted, etc.) ,il , a2. ~IST Or ~,~kcte~&STS [ V,,'~LI., STATUS (Producing or J TE~IT WITNESSED BY 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-i~,allable records - , 7-~-1~ , *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well cor'r~pletion report and log o~] 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, prc. duction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~c:]uci~,g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv~l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce.d, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of ~ny 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). ,, ~{.' SUMMA. I~Y O~ ~'O~MATION TF~'I'S INCLUI)IN(; IN'lJEI~.VAI., TF_~STED, i:'R]g.S~qUIllg DATA- AND ~COVERI~'OF OIL~ GAS.- 35. G~GIC MARK~ WAT~I AND MUD ,, -., 38. C~ DATA.-Aq'rACI{ BRIEF P. O. BOX 7-839 · ANCHORAGE ° ALASKA PRODUCING DEPARTMENT TELEPHONE BR. 7--6201 C. V. CHATTERTON DISTRICT SUPERINTENDENT August 3, 1961 Mr. D. D. Bruce Alaska O & G Conservation Cormmission 329 Second Avenue Anchorage, Alaska Dear Sir: Enclosed, herewith, is the Completion Report for Swanson River Unit Well 21-27 (18), for your information and files. Very truly yours, STAND~RD OIL COMPANY OF CALIFOR3~IA We st er~Op er at io~,.~uc o Enc !os ur e COMPLETION REPORT - NEW WELL STANDARD OIL COMPANY OF CALIFORNL~ WESTERN OPEK~TIONS~. INC. - OPERATOR ~ :: '_ L. ~ ,' ', ' .! · .- u'~":_: t · · . : :~ .- -: - ' . / ' - "' . ' ' · _-'= -' : ' ~'--;~. "'-~'-" b' "· ' AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND oFFICE: Anchorage Lease No.: 028406 PROPERTY: Swanson River Unit N0.: SRU 21-27 SECTION 27, T. 8 N., R. 9 W., SEWARD B & M LOCATION: Surface: 630' south & 2195' east from northwest corner, Section 27 (Proj.) T.-8 N., R. 9 W., Seward B ELEVATION: 199' K.B. DATE: August 2, 1961 BY: · K.B.As 15' above ground. C.~'V~HATTERTON~, Distridt S~perl'nt'e~nt' DRILLED BY: Coastal Drilling Company (Rig $3) DATE COMMENCED DRILLING: March 18, 1961 DATE COMPLETED DRILLING: M~y 5, 1961 DATE OF INITIAL PRODUCTION: PRODUCTION: Daily Average 520 o11.......... 515 'Water 5 Gas.. ....... , 83 May 8, 1961 Flowing Gravity ..... 34.1 TP... · ...... 1425 psi Bean 9/6;+" SUMMARY TOTAL DEPTH: 11,142' PLUGS: 11,142 - 11, 000' JUNK: None CASING: 20" conductor cemented at 40'. 11 3/4" casing cemented at 2029' in one stage with 1350 sacks around shoe. 7" Casing cemented at 11,142' in one stage with 2200 sacks around shoe. COMPLETION REPORT - PACKER A~D GAS LIFT INSTALLATION STANDARD OIL COMPANY OF CALIFORNIA~ WESTERN OPERATIONS~ INC~ - Operator AREA: Kenai Peninsula, Cook Inlet, Alaska PROPHRTY: Swanson River Unit LAND OFFICE: Anchor age LEASE NO.: A-O28h06 WELL NO: SRU 21-27 Section 27 T. 8 N., R. 9 W., Seward B & M LOCATION: Surface: 630' South and 219~' East from Northwest corner of section 27. ELEVATION: 199' K. B. K. B. is l~' above ground DATE: June 2h, 1963 C.V. CHATTERTON, District Superintendent CONTRACT(R: Santa Fe Drilling Companv, Rig #35 DATE COMMENCED REMEDIAL WfRK: December 28, 1962 DATE COMPLETED REMEDIAL WORK: January 1, 196~ TOTAL DEPTH: 11,1~2 ' SUMMARY PLUGS: 11,000' - 11,1~2 ' CASING: 20'~ cemented at ~0' ll 3/~" cemented at 2029' 7" cemented at ll, l~2' COMPLETION REPORT - PACKER AND GAS LIFT iNSTALLATION SWANSON R~YER UNIT 21-27 Section 27 T. 8 N., R.. 9 W., Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - Operator December 28~ 1962 Commenced rigging up at 12:01 AM. Conditioned Black Magic Mud. December 29~ 1962 Killed well, removed x-mas tree and installed BOPE. Pulled 2 7/8" tubing loose and ran to 10,919' and circulated. December 30, 1962 Pulled tubing out of hole and ran casing scraper. Conditioned mud. December 31~ 1962 Pulled scraper and reran 2 7/8" tubing equipped ~th packer and mandrels. All tubing (336 joints) is 2 7/8", 6.5#, N-80 EUE 8R R2. TUBING DETAIL K.B. Depth K. B. to~onut Donut 2 pup joints 45 joints 2 7/8" tubing' Camco MM Mandrel w/RD (#1) 46 joints 2 7/8" tu~ng Camco MM Mandrel w/RD (#2) 41 joints 2 7/8" tubing Camco MM Mandrel w/RD (#3) 33 joints 2 7/8" tubing C ~amco MM Mandrel w/RD (#4) 30 joints 2 7/8" tubing Camco MM Mandrel w/RD (#5) 26 joints 2 7/8" tubing Camco MM Man rel w/RD (#6) 22 joints 2 7/8" tubing Camco MM Mandrel w /RD (#7) 87 joints 2 7/8" tub4ng Camco MM Mandrel w/CEV (#8) i joint 2 7/8" tubing Brown 2 7/8" safety joint i pup joint Brown 2 7/8" X 7" HS-16-1 packer 2 joints 2 7/8" tubing Camco "D" Nipple 3 joints 2 7/8" tubing Venturi Shoe Tubing landed at 15.00' 7.85' 23.70' 12.98' 1457.83' 13.01 ' 2925.46' 1293.89' 4419.35' 13.02' 4432.37' 1040.13' 5472.50' 13.o5' 5485.55' 947.44' 6432.99' 13.00' 6445.99' 821.50' 7267.49' 13.00' 7280.49' 696.38 ' 7976.87 ' 13.05' 7989.92' 2749.68' 10,739.60' 13.11 ' 10,752 · 71 ' 31.51' 10,784.22' 1.06 ' 10,785.28' 10.15' 10,795.45' 5.98 ' 10,801.41 ' 62.94' 10,864.35' · 92 ' 10,865.27 ' 94.99' 10,960.26' · 45 ' 10,960.71 ' 10,960.71 ' COMPLETION REPORT - PAcKE?. A~D GAS LIFT INSTALLATION SWANS ON R IVEH UNIT 2~-27 Section 27 T. 8 Nm, R. 9 W., Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WEST~N~OPERATiON~'~ INc. - Operator Removed BOPE and ins,tailed x-mas tree. Displaced mud with oil. January l~,, 1963 Set packer at 10,795' and returned well to production. Rig released at 5:00AM. S.R. NANSEN sat WELL RECORD INVENTORY Field: Swanson River Unit Location ~ TSN.R.9.w,. se.c.. 1.27,_ _se[V[. .... Operator & We1! Name: ........... Standard Oil Co. ...... un~.t:...~2 !,-.2 7. No. Pages 1. Drilling Permit: 2. Survey Plat: 3. Monthly Reports (P-3): Completi on Report (P-7): 5. Well History: 6. Other: 7. Mi s cel 1 aneous: 8. Deviation Survey(s): Total Pages: I 9. Wel 1 Logs: _(l) SL (2) CCL & PI{ _(3) CBND (5) ~6 ) IEL (7) .......... (8) (9) COMPLETION REPORT SWANSON RIVER UNIT WELL NO. 21-27 Section 27,~ T. 8 N:...,~ R. 9 W~, 8e~rd s~~ o~L cO. 'o; ~;o-~D~, w.o.~. Page 2. PERFORATION RECORDS: ~" Jet holes at 10,672' · !" jet holes/~ft! 10,676 - 10,696'! "jet holes/~ft 10~710 10,773' "Jet holes/ft 10,778 - 10,805 ' LOG RUNS: ~.) ~.) ~.) Schlumberger 1ES log, interval 11,140 - 2,0S6'. Schlumberger Sonic log, interval 11,13~ - 2, 0S6' · Schlumberger Micro log, interval 11,140 - 9,400'. Schlumberger Neutron Collar log~ interval 10~ 980 - 9, ~80'. Schlumberger Cement' Bond log, intervml 10,990 - 7,000'. DRILL STENI TEST: 1.) HCT WSO on perf'd, interval at 10,672' (WSO). COMPLETION REPORT SWA SO 0.2 -S7 SECTION 27 (P~J.) T. 8 N~, R. 9 W., SEWA~ B & M Page 3. March !8, Spudded at 2:00 PM 3-18-61. Drilled 16" hole 0 - 252' 252' drilled 75 pcf mud Drilled 16" hole 252 - 312' 60' drilled Drilled 15" hole 312 - 2,035' Reamed hole 190 - 1,110' 1,:723' drilled 82 pcf mud March 20, .1961 Reamed hole 1,110 - 2,035'. Circulated and conditioned mud. Ran 11 3/4" casing, casing stopped at 215'. P. O. casing. Ran in reamed hole to bottom. Made one more conditioning run. Circulated and conditioned mud. Ran 51 Joints of 11 3/4" casing. Landed casing at 2,029'. March 21, 1961 Cemented casing as follows: CEMENTING ~ETAIL: Cemented 11 3/4" casing at 2,029' around shoe with 1350 sacks of cement treated with O. 3% HR-4 using Halliburton power equipment. Used one top and one bottom rubber plug. Pumped 50 bbls. of water ahead, mixed 1350 sacks of cement in 50 rains, using Halliburton truck, displaced in 28 mlns. using rig pumps. Average slurry weight 116~. Full circulation throughout and good returns. Cement in place at 8:45 AM. CASING DE~AIL: 51 Joints or 2,047.41' Above K.B. 17.58 L _ Casing Landed at 2,029.83' equipped with Baker guide shoe and float collar. COMPLETION REPORT SWANSON RIVER UNIT WEIJ.~ NO. 21-27 ~c~ON ~? (~..ro.~..) ~: ~..~.,. ~. ~ w,,-.s~.w~.~_~ ~ ~ s~ on, co. OF CA~O~, W:O.~. --O~E~A~OR Page March Cut conductor pipe. Had Water flow between conductor and casing. Ran 1" pipe to 70' in annulus. Pumped in cement to surface and stopped water flow. Commenced flanging up. Flanged u~. Installed and tested BOPE with 1500 psi. OK. Tested Blind Rams with 1500 psi, 15 rains. OK. Tested Kelly Cock, pipe rams and Eydril with 1500 psi, 15 rains. OK. Drilled out cement and shoe. Drilled lO 5/8" hole 2,035 - 2~885'. 850' drilled 80 pcf mud Drilled 10 5/8" hole 2,885 - ~,ll~' 1,227' drilled Drilled 9 7/8" hole 4, ll~ - 4~ 197' 85' drilled 81 pcf mud March 24 - March.3!,_. 1961 Drilled 9 7/8" hole 4,197 - 7,489' 3,292' drilled 81 - 95 pcf mud April_l, 1961 Lost circulation. Pulled to 3,000' not regained. Pulled out. Cut mud back to R4 Pcf. Lost 150 bbls. D~llea 9 7/8" ho~e 7,489 - 7,609' 120' drilled 99 pcf mud Ap _ri. 1 S, 19_61 Mud 95 pcf at 8:00 AM. Lost circulation, i bbl. mud weight from 95 pcf to 98 pcf to prevent gas entry. tained. Drilled 9 7/8" hole 7,609 - 7,7~6' 117' drilled 98 pcf mud Lost every 5 rains. Increased Full circulation ob- COMPI~TION REPORT SWANSON RIVER UNIT ~ELL NO. 21'27 ~STA~ O?L CO. OF CAL~FO~ W.O.~. Page 5- April 3 - April 2~, 196~ Oriiled 9 7/8" hole 7,726 - ll, lg2' T.D. 3, ~16' drilled 97 - 98.5 pcf mud Ran IES log to 1i, 142'. Started out with IES log and line pulled into keyseat at 3,000'. Worked line trying to get loose. Ran Bowen Socket on ~" drill pipe over Schlumberger line. Took hold of fish at ll, ll7'. Pulled loose~ chained out. Recovered fish. Ran in and cleaned out 10,980 - 11,142'. Cir- culated. 98.5 pcf mud Ban IES log, interval 11,140 - 2,O36'; Sonic log, interval 11,134 - 2,0~6'; and Micro log, interval ll, 140 - 9,400'. Circulated and conditioned mud. 98.5 pcf mud Ran 264 joints of 7" casing. CEMENTING DETAIL: Cemented 7" casing at 11,142' in one stage with 2200 sacks of cement treated with O. 3~ ER-4 using Halliburton power equipment. Used one top dud one bottom plug.. Cemented around shoe with 2200 sacks of cement. Pumped 50 bbls. of water ahead, mixed 2200 sacks of cement in 40 rains, using Halliburton truck, displaced in 45 rains, using rig pumps. Average slurry weight ll6~. Did not bump plug. 2000 psi. Full circulation. CASING DETAIL: Top ~ joints or 171.29' NeXt 22 Joints or 931.22' Next 88 Joints or 3,691.47' Next ~2 Joints or 1,800.19' Next 43 Joints or 1,814.97' Bottom 65 Joints or 2~ 7~4.17 ' ~L. ~ ~. :; :'~ "" "' : : "' - ~ ' ALL 26~ Joints or 11,153.31' Above K.B. ; 11.31' 7", 29~, P-110 BT 7", 26~, N-80 BT 7", 235, N-80 BT 7", 265, N-80 B~ 7", 29~, P-ilO, BT 7", 29~, P-110, 8 R Equipped with Baker shoe and collar one Joint above. Lmn~ed casing at 11,1~2'~ COMPLETION REPORT s mso mw a STA~ OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 6. Installed tubing head flange. Tested primary and secondary packoff to 3500 psi. OK. Installed and tested BQPE. OK. Located top of cement at 9, 358'. Drilled, cleaned out cement 9, 356 - 9, 511' · 96 pcf mud Drilled, cleaned out cement 9, 53-I - lC, 125'. Drilled, cleaned out cement lC, 125 - 11,000'. Ran Neutron Collar log, interval 10,980 - 9,980'. Jet ~erf'd. 5 - ~" holes at 10,672'. Prep. for WSO test. Ran WSO Test ~1 on 5 - ~" holes at 10,672'. WSO TEST: Tool assembly as folloWs: 2 outside BT recorders, 5' of 2 7/8" perf'd tail pipe, 7" type "C" hookwall packer, VR safety joint, hydraulic Jars, 2 inside BT recorder, hydrospring tester, and dual closed in valve. Used 2,699' of W.C. Ran on 10,617', 2 7/8" drill pipe. Set packer at 10,640' with 19' of tail to 10,659'. No ISI pressure. Opened tool to surface at 10:26 AM for one hour flow test. Puff blow and dead. Shut in tool at 11:26 AM fOr 33 min. FSI pressure. Pulled packer loose at 11:59 AM. Recovered 40' net rise. All drilling fluid. PRESSURE DATA: IH IF FF FSI FE Top inside 6991 1268 1268 1335 6991 Bottom inside 6952 1240 1240 1304 6952 Top outside 7061 1258 1258 1317 7061 Bottom outside 7050 1260 1260 1320 7050 Charts indicate tool open. Ran Cement Bond log, interval 10,990 - 7,000' Eemlock Zone. . Good cement bonding through COMPLETION REPORT SWANSON RIVER UNIT ,JELL NO. 21-27 s~.cTIo~ 27 (~j.)_~.~._ .8:.~.,. ~. 9...~,., .SS~RD ~ ~ ~ S~ OIL CO. OF CALIFOR~, W.O.I. ' oPErATOR- Page 7. Ran 2 7/8" tubing to 10,991'. tubing at 10, 628'. Displaced mud with oil. Pulled up and landed TUBING DETAIL: 336 Joints or Pup joint Donut to tubing K.B. to tubing head Landed tubing at 10,606.62' 6.00' 2.00' 14. O0 ' 10,628.62 ' 2 7/8" sus, N-8o, 8 R Flanged~Up Xmas tree. Tested tree to 3500 psi, OK. Ran casing collar log. Ran string of shots to Jet perf., shots would not fire. Prep. pull out of hole. Pulled Schlumberger line out of hole, leaving string of shots in hole. Ran sinker bar on Schlumberger line to locate 1st string of shots. Chased shots to 10,870'. Ban 2nd string of shots. Shots did not fire. Pulled 2nd string of shots out of hole. Ran back in hole and Jet perf'd, the following intervals: 10,676- 10,696'; 10,710 - 10,773'; 10,778 - 10,805'. Prep. to complete well. COMPLETION DETAIL: Installed Xmas tree and tested with 3500 psi for 5 rains., held OK. Displaced mud with oil. Started well to surface at 3:30 AM. Flowed oil to sump until 7:00 AM. Started flowing to trap at 7:00 AM. Representative flow rate and cuts as follows: Flow Rates Bean Tubing Casing Trap ~0w, .Period Oii-. . ............... G~s~_ _ Size_ ..... Press- Press..~, : ~ Press. i.) ~ hr. i6o8 B/,D i46 MCF/,D i8/64" 92~ 805 7~ 2. )~ hr. 994 B/D 73 MCF/D 14/64" 1220 1050 75 ~ To.tm!....Cut ¢ Water ~. Enm!Sio~ .~. Sand..._&:m~._d_ C._or.r, Gravity__ i.) 0.6 o.~ 0.2 Trace 34.4 2.) 0.~ 0.2 0.2 -- Shut well in at 8:30 AM. Shut in pressures; Tubing pressure 1550 psi; casing pressure 1~20 psi,, Produced estimated 309 bbls. formation oil. Flowed 379 bbls. to tank and estimated 379 bbls, to sump. Installed cosasco plug. SE; lo STEINAR NANSEN COMPLETION REPORT SWANSON RIVER UNIT WELL NO. ~1-27 SECTION 27 (ProJ.) T. 8 N,~ R. 9 W. SEWARD B & M ~A~" O~n cO~ -'0~ CA~~, ?w~O'~:', o~-p~o-~ Page 8. DEVIATION DATA .- : · . :_ ~ .30' 15' ~5' 50' 15' 50' 30' ~5" ~5" 30' UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ]~udg,~t Bureau No. Approval 0xpirt~s 12- ;H LAN[~ OFFICE . Anchorage .~ ..,~._028406 U~,t ..... ~an~oI1. ~qLV_ LESSEE'S MONTHLY REPORT OF OPERATIONS TAe followD:,~ is ~ correct' revorL of ope;rettio;t,.~ ~tn,d orodtt, ction, finclu,lin.~ drillin..~ a~d ~)rodu, r. in6 welLs)for th, c ~ontl, of .......... ~aY ........... Il/ 61 Sw~son River Unit ~e~ ~ aac~r~,.,~ .... 'r. ..... t-~ ~Y ............... %mp,,,,//~eotern ~ra~!gns, ,zn$, . , . SRU 21-2 7 (18) i : 27 8N ~g Drilled out cement 10,125~ - 11,000'. Ran ocbl~be~g~r' ~ Neutron Coll~ Loca~or log, ~nd Cement Bond Lo~. Est~blimhed WS0 on boles NE~ at 10,672~. Layed do~m drill pipe. R~ 2 7/~" tubing to 10,~01', ~ ' Changed over to oilo Pulled uo ~d l~ded tubir~ at 10,62~'. Installed x-mas tree ~d tested .~th 3500 psi. OK. Attempted to ~ jet~ perforate production interval. Left st~ing shot tn hole. ~ 2nd~ string. F~led to fire. Jet oerfor~t~ follo~ng intervals ~. thru tubing: 10,676' - 10,696', 10,710~ - ~0,77~', 10,778' - 10,805'. ~ Well started flowing at ~:OO AM May ~, 1961. Flow rates: 1608 {B/D~ oil, 146 MCF/D gas, ~8/64" beam, 925~ tubin~ pressure, { casi~ pressure 7~ tr~. press~e 34.4c gravity, 0 ~% total cut. ~ ~g~rele~sed 9:~0 ~M MaE 5, 1961. U.S.GoS. - Mez~in H!. Soyster 2) ........... ~ G. (,C -__ Ric~ield Oil Co~.: - C. W. P~r~ ~ ~ R.H.E.tter 0his 0il Co. V George Sowards U~on Oil Co. ~- C. E. S~th Files: ProduCing F~xploz'atior~ Land NoT~.--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................. runs (,r salc,s of gasoline during the month. (Write "m)" wh('?c :~l)plicable.) NoTtc.--Rcport on this form is required for each calendar month, regardless of thc ~tatus of operations, and must be filed in duplicate with thc supervisor by ~he 6tt~ of the succeeding month, tlnless otherwise directed by ih,~ supervisor. · ~rm 9-229 UNITED STATES DEPARTM£Nq' OF THE iNTERIOR GEOLOGICAL SURVEY MONTHLY REPORT OF OPERATIONS 27 I 8N Td ,!ati~ obtained~ DPt].]_m 9 7/8" hole 7726~ - It,i42' og r~. f~om ~].,~2'. S~de stuc]~ on bottom. ,an i.~, oo~c, ~cro lo~s. Ceme~lt~ 7" easi~ at acks.~ Plus noSbm~d~u~inE c~nt job~ Tie se~g oz~ ~left h~le th~o~h center of plug. - C. W. -R. tl0 R:.tter ~. $~ith Nc~r~.--The~ were ........................................ run~ or sales of oil; .................................................... lki au. fL. of g~z ~old; .................................................. runs or saias of gasoline during the month. (Writ~ "nc;' where applicable.) No~z.--}%eport on th~ form ~ ~quir~ for ~ch ~lendar month, ;~gardl~ of the ~tatu~ of operations, and duplica%e with the su~v~or by the 6th of the succe~i~ month, u~s othe~e dArec~d by the 8u~rvisor, (~ ~) UNITED STATES DEPARTMENT OF THE _~NTERIOR GEOLOGICAL SURVEY LE SEE'$ MONTHLY REPORT OF OPERATIONS ~ followi~ is a oorree~ report of op~ration~ and production (gnoludt~&~ drillin~ and ~ S~ D OIL. QO~ ~~HNIA Noen.--Them were ....................................... run~ or ~aies of off; ............................................... M ~. f~. of g~ ~d; ................................................. runs or ~ of $~otine during the month, (WMte "no" whe~ ~pp~ble.) No~m.~Re~ on ~ fo~ i~ ~qu~ for ~ch calendar month, ~g~e~ of the ~tatus of o~rations, and m~t be filed in dupli~ with the su~rv~or by the 6th of Che succ~i~ month, uMess othe~Me directed by the su~rvisor. Feb. 1¢61) (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY mat__. S_~o n__Ri~r .... SUNDRY NOTICES AND REPORTS ON WELLS I 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 WEL.L .................... i _ _ . - i SUBSEQUENT REPORT OF WATER SHU'I'-O4~F SUEK~EQUENT REPORT OF SI~OOTING OR ACIDIZI~ ............... i .... SUBS~OUENT REPORT OF ALTERING C.J~ING ...................... SUBSEQUENT REPORT OF RE-DRILLIN~ OR REPAIR ............. I ..... SUBSEQUENT REPORT OF A~k~N[)ONMENT ............... SUPPLEMENTARY WEL.L HISTORY .................. ! ..... (INDICATE AI~VE BY CHECK MARK NATURE ~ REPORT, NOTICE. O/t OTHER DATA) 61 appr°ximately'N}__. Well No. S~_ . 21-21 is locate/_ ~0 ft. from__-~g line and ~ ft. from line of s~ .... ~ ..... ~ r~jec~d ~ ....... ~_t_~. ~_~.~ a.~ _? _W (~ ~c. and ~c. No.) (Twp.) (R~ge) (M~di~) (Field) (County or Subdivision) (S~ ~ Terrify) The eievation of ~he ~ a~ve s~ level is .... 20~ ft. DETAILS OF WORK inI points, and all other important pro~cl 3. Drill to 2Ct~O' and cement !i 3/4' easing. install and test Class III Blowout Prevention Equipment. Drill ahead to app~mxima~ely ll, OOO' log and cement ~" casing in a single stage ' Obtain ~quisi~e water shut offs. Selectively Jet perfo~te attractive sands and test as mecessary. Run 2 7/8" tubing and complete. ~~ ~ Address APPLICATION FOR~ 'PERMIT TO" DRiLlI DEEPEN OR PLUG BACK .'.-~ _ . APPLICATION .TO-DRILL:~ ,- DEEPEN ~-] NAME OF COMPANY OR OPERATOR Address ............. ~ '- ~ ~ J'~'~/-':~?.~ ...... ' ~ :~'-- ~: '~ '~ .~ ~ ~ State Name of lease ' -_ --':c: ~'~ ~-~ ---. ~:~ ' '~q¢~ll humber '-:-.--:.::" : ;~-';: -: ~ - '~ . _ ~t [ Elevation... (ground) TYe]l loca(ion (give footage'from section lines) Section--~ownship--ran~e or'bloc~'& survey Distance, in miles, and .direction from .nearest' town ~P post Office ~O~rest distance f~om PrO¢~sed location ~ ' ' D~stanee from proposed location to nearest drilling, to property or lease l[n~: completed or applied~for well on tho same leReo: ~roposed depth: Retry or cable tools Approx. date work will start PLUG BACK.i-] feet Number of acres in lease: If lease, .purchased with one or more Name wells drilled, from whom purchased: .[ Number of wells on lease, including this well, completed in or drilling to this r~servoir: -- Address Status of bond Remarks: (If this is an application ,to deepen or plug .back, briefly describe work to be done, giving present producing Zone' and expected new produ~ii!g zone)- iv{as ~ 1961 ~, i.; ncrals CERTIFICATE: I, the undersigned, state that I am the~,~g[_~ ~-~of the~~ (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated ther~oar, e tr~ue,,correc~ and complete to ~.,,rlg{nal s~gnea the best of my knowledge. J.T. CROOKER Permit Number: 10-61 ~r~ow~ O~e: . March 1. 1961 / - State Geologist Notice: Before sending in this form be sure that you have given ali information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Signature Alaska Off and Gas Conservation Commission Application to Drill, Deepen or Plug Baek Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958