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DIO 028
INDEX DISPOSAL INJECTION ORDER NO.28 and 28A Deep Creek Unit NNA No. 1 Well 1.October 4, 2004 2.October 8, 2004 3. November 9, 2004 4. November 9, 2004 5. November 16, 2004 6. November 24, 2004 7. December 21, 2004 8. -------------------- 9 - -------------------- 10. July 16, 2007 11. November 26, 2007 12. December 16, 2010 Unocal's application for DIO Notice of hearing, affidavit of publication, email distribution, and mailings Sign -in sheet Transcript Unocal's answers to 11/9/04 hearing questions Unocal's letter of clarification Emails: Methanol Spilled at Happy Valley Monthly Pressure Reports Annual Disposal Reports Memo to Files Email: Request to Dispose Precipitation in NNA-1 (no action needed by AOGCQ Email: Delinquent Annual Reports ORDERS 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7 Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Union Oil ) Disposal Injection Order No. 28 Company of California for disposal ) of Class II oil field wastes by ) Deep Creek Unit underground injection in the Tyonek ) NNA No. 1 Well Formation in the Deep Creek Unit ) NNA No. 1 Well, Section 11, T2S, ) R13W, S.M. ) December 7, 2004 IT APPEARING THAT: 1. By correspondence to the Alaska Oil and Gas Conservation Commission ( "Commission ") dated October 1, 2004 and received on October 4, 2004, Union Oil Company of California ( "Unocal ") requested authorization to allow the underground injection of non - hazardous Class II oil field waste fluids into the Tyonek Formation within the Deep Creek Unit NNA No. 1 ( "NNA #1") well bore. The well is located on the Kenai Peninsula approximately 6 miles east of the city of Ninilchik; 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on October 8, 2004 in accordance with 20 AAC 25.540; 3. The Commission did not receive any protests to the application, comments, or requests for a public hearing; 4. A hearing was held on November 9, 2004, at which Unocal provided sworn testimony addressing engineering and geologic considerations in support of the NNA #1 disposal injection order application. The record was held open to allow Unocal to provide supplemental information about the confining lithologies isolating injected waste fluids from shallow freshwater aquifers as requested by the Commission; and 5. Unocal provided supplemental information addressing fluids eligible for disposal into NNA #1 in a letter dated November 24, 2004. II' Disposal Injection Order 28 • Page 2 of 7 NNA No. 1 Well December 7, 2004 FINDINGS: 1. Location of adjacent wells (20 AAC 25.252 (c)(1) NNA #1 is a near- vertical well that is located approximately 272 feet from the south line and 510 feet from the west line of Section 11, Township 2 South, Range 13 West, Seward Meridian. There are no wells within 1/4 mile of the NNA #1 well; 2. Notification of Operators /Surface Owners (20 AAC 25.252 (c)(2) and 20 AAC 25.252 (c)(3)) Unocal is the only operator within '/ mile radius of the proposed disposal operation. The sole surface owner within a % mile radius of the NNA #1 well is Ninilchik Native Association, Inc. Unocal provided evidence that a copy of its application for disposal injection in the NNA #1 well was sent by certified mail to Ninilchik Native Association, Inc., on October 1, 2004; 3. Geologic information on disposal and confining zones (20 AAC 25.252 (c)(4)) Unocal proposes to conduct disposal into the Tyonek Formation ( "Tyonek ") between the measured depths of 6,182 ft and 9,278 ft. Individual sand intervals within the Tyonek Formation were perforated after drilling to test for natural gas; no commercial gas rates were achieved. Disposal operations in NNA #1 will not impact adjacent production from the Happy Valley field as the nearest development wells are approximately 2 miles away; Geologic information provided by Unocal notes that the Tyonek Formation consists of interbedded conglomerates, sandstones, siltstones, shales and coals deposited in fluvial, lacustrine, alluvial, and terrestrial systems. Sandstones within the proposed disposal interval have estimated porosities up to 22 %, permeabilities in excess of 20 millidarcies, and can approach 40 -ft in thickness (average 20 ft). Unocal has provided evidence that the numerous coal beds ranging in thickness from 6 inches to 30 ft, as well as tight carbonaceous and impervious claystone beds provide vertical confinement for injection into the Tyonek. The Beluga Formation is several thousand feet thick and occurs at depths greater than 2,000 ft in the Deep Creek Unit. This formation is comprised of thinly laminated sandstones, siltstones, shales and coals. Individual sandstone beds within the Beluga Formation are generally less than 30 ft thick, resulting in a heterogeneous sequence of rocks with very poor or no vertical connectivity or permeability. In the area considered for disposal injection, the top of the Beluga Formation is at a depth of approximately 2,400 ft and marked by locally continuous, 75 -ft thick shale. ' All depths noted in this Order are measured depth ( "MD ") referenced to NNA #1 and are substantially equivalent to true vertical depth ( "TVD ") below ground level in this near vertical well. Disposal Injection Order 28. • Page 3 of 7 NNA No. 1 Well December 7, 2004 Supplemental information provided by Unocal on November 17, 2004 identifies more than 1,000 ft of confining lithologies between the aquifer exemption depth (1,800 ft per AEO No. 11) and the depth of uppermost injection perforations (6,182 ft); 4. Well Logs (20 AAC 25.252 (c)(5)) Well logs from NNA #1 are on file with the Commission; 5. Demonstration of Mechanical Integrity and Disposal Zone Isolation (20 AAC 25.252 (c)(6)) Drilling records show that Unocal ran 7" casing and cemented it with 172- barrel lead and 66- barrel tail cement slurries. An Ultra -Sonic Imaging Tool (USIT) was run in the well 4 days after cementing 7" casing to evaluate the cement sheath in the vicinity of the disposal intervals, focusing specifically on the interval from 5,700 ft to 6,182 ft. Analysis of the USIT results indicates competent cement around the 7" casing below 5,860 ft, isolating the uppermost injection interval with approximately 320 ft of cement. Unocal conducted a successful 3000 -psi mechanical integrity test of the tubing - casing annulus in NNA #1 on August 24, 2004. The pressure test was performed in accordance with 20 AAC 25.412(c); 6. Disposal Fluid Type, Source, Volume and Compatibility with Disposal Zone (20 AAC 25.252 (c)(7)) The primary disposal fluid planned for this well is formation fluid from the Happy Valley Field as well as approved Class II fluids from other Unocal operated fields. Specific wastes include drilling, completion, production, and workover fluids; stimulation fluids and solids; tracer materials; rig wash fluids; glycol dehydration wastes; drilling mud slurries; naturally occurring radioactive material scale slurries; tank bottoms; and other fluids brought to surface and generated in connection with oil and gas development activities. Unocal estimates a maximum of 3,000 barrels per day of fluid will be injected in NNA #1; 7. Estimated Injection Pressure (20 AAC 25.252 (c)(8)) Unocal estimates average surface injection pressure will be 2,200 psig and the maximum surface injection pressure will be 4,000 psig; 2 Maximum injection pressure clarified in public hearing record for DIO 28 (November 9, 2004), pgs 9 -10 Disposal Injection Order 28. Page 4 of 7 NNA No. 1 Well December 7, 2004 8. Evaluation of Confining Zones (20 AAC 25.252 (c)(9)) The potential to fracture through the confining lithologies at the NNA #1 well was modeled by a Unocal consultant. Included in the consultant's analysis was experience from observed behavior of Beluga - Tyonek facture treatments in the region. The goal of this evaluation was to predict the expected upward fracture growth for cuttings disposal at NNA #1 using worst -case assumptions. The simulation assumed continuous 2 -day injection of 8,000 barrels of slurry in 10 equal events separated by 59.5 - barrel sweeps with clean fluid. Slurry make -up was assumed to have a 12 percent solids concentration with 30/50 -mesh sand distribution and density of 10 pounds per gallon. Injection rate for the modeling work was 2.5 barrels per minute. Only the uppermost perforated interval (6,182 ft — 6,222 ft) is assumed open. In this worst -case model, the critical factor is vertical fracture propagation, with a critical limit being the log- derived top of cement in the production casing annulus (5,860 ft, or 322 ft above the top of perforations). The fracture analysis indicates that coal intervals overlying the injection interval tend to impede the fracture height growth within the Tyonek Formation. Modeling shows the fracture height is not expected to grow beyond the top of cement. Unocal further notes that the injection assumptions included in the modeling work significantly exceed maximum estimated fluid injection per day; 9. Standard Laboratory Water Analysis of the Disposal Zone (20 AAC 25.252 (c)(10)) A laboratory analysis of formation water sampled from one of the Tyonek sands in NNA #1 identified total dissolved solids greater than 7,000 ppm; 10. Aquifer Exemption (20 AAC 25.252 (c)(11)) Pursuant to a separate proceeding, an aquifer exemption has been granted, in Aquifer Exemption Order No. 11, for depths greater than 1,800 ft covering 3 specific areas within the Deep Creek Unit: - A % mile radius around NNA #1; - All of Section 22, which includes the Happy Valley pad and associated wells; - The southeast one - quarter of Section 15; and - All of Section 21, which will cover a new drillsite and associated wells planned by Unocal for the Deep Creek Unit; and 11. Mechanical Condition of Wells Penetrating the Disposal Zone within '/ Mile of NNA #1 (20 AAC 25.252 (c)(12) There are no wells penetrating the disposal zone within % mile radius of NNA #1. Disposal Injection Order 28 Page 5 of 7 NNA No. 1 Well December 7, 2004 CONCLUSIONS: 1. The application requirements of 20 AAC 25.252(c) have been met; 2. Mechanical integrity of the tubing - casing annulus to a depth of 6,097 ft has been demonstrated in the NNA #1 well by pressure test. Competent cement has been demonstrated in the casing annulus to 5,860 ft. The NNA #1 well has been cased and the casing cemented in a manner that will isolate the disposal zone and protect oil, gas, and freshwater sources; 3. At NNA #1, there is approximately 180 ft of confining lithologies between the top of cement in the 7" casing annulus and the uppermost perforations. While other confining lithologies are documented, the Commission does not recognize these as effective confining zones since the uncemented annulus above 5,860 ft provides a communication path for fluid migration up hole should the 180 -ft net thickness be compromised; 4. Worst -case fracture modeling confirms that waste fluids will be contained within the receiving intervals by the confining lithologies within the Tyonek Formation, cement isolation of the well bore and operating conditions; 5. Disposal injection operations in the NNA #1 well will be conducted at rates and pressures below those estimated to fracture through the confining zones. Therefore, oil field wastes will not enter freshwater strata; and 6. Supplemental mechanical integrity demonstrations and surveillance of injection operations are appropriate to ensure waste fluids are contained within the disposal interval. Included are mechanical integrity testing, temperature surveys, monitoring of injection performance (pressures, rates), and analysis of the data for indications of anomalous events. NOW, THEREFORE, IT IS ORDERED THAT: RULE 1: Authorized Injection Strata for Disposal Injection of authorized fluids for purposes of underground disposal of oil field wastes is permitted into the Tyonek Formation below 6,000 ft in NNA #1 well. The Commission may immediately suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated injection strata. RULE 2: Authorized Fluids This authorization is limited only to Class II waste fluids as follows: produced water, drilling, completion, production and work over fluids (including stimuilation fluids and solids, and tracer materials), rig wash, drilling mud slurries, NORM scale, tank bottoms, and glycol dehydration wastes. The Commission may authorize the disposal of additional Disposal Injection Order 28. • Page 6 of 7 NNA No. 1 Well December 7, 2004 fluids not identified above on a case -by -case basis if the Commission determines they are suitable for disposal in a Class II well. RULE 3: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, and before returning a well to service following a workover affecting mechanical integrity. A Commission - witnessed mechanical integrity test must be performed after injection is commenced for the first time in a well, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Subsequent tests must be performed at least once every four years thereafter (except at least once every two years in the case of a slurry injection well). The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1,500 psi or 0.25 psi /ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. Results of mechanical integrity tests must be readily available for Commission inspection. RULE 4: Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall notify the Commission by the next business day and submit a plan of corrective action on a Form 10 -403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. RULE 5: Surveillance The operator shall obtain a baseline temperature log and a baseline step rate test prior to p p g P p initial injection. A subsequent temperature log must be performed 1 month after injection begins to demonstrate the receiving zone of the injected fluids. Additional temperature survey requirements will be based on the results of the initial and follow -up temperature surveys. An annual report for the calendar year evaluating the performance of the disposal operation must be submitted by July 1 of each year. The report shall include pressures, fluid volumes (disposal and clean fluid sweeps), fluid make -up, injection rates, an assessment of fracture height growth, and a description of any anomalous injection results. During the first year of injection, a monthly evaluation of injection monitoring results must be provided to the Commission with an emphasis on fracture height growth. Disposal Injection Order 28. ill Page 7 of 7 NNA No. 1 Well December 7, 2004 RULE 6: Notification of Improper Class II Injection The operator must immediately notify the Commission if it learns of any improper Class II injection. Additionally, notification requirements of any other State or Federal agency remain the operators' responsibility. RULE 7: Administrative Action Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. RULE 8: Conditions It is a condition of this authorization that operations be conducted in accordance with the rules set out in this order, with AS 31.05, and (unless specifically superseded by Commission order) with 20 AAC 25. Failure to comply with an applicable provision of AS 31.05, 20 AAC 25, or these rules may result in the suspension or revocation of this authorization. DONE at Anchorage, Alaska and dated D- - . t 7 0:4 I p, OIL Az I - ,. an, Chai '%-''', \ \ / rilli '' 1p Alaska Oil and Gas Conservation Commission �f a '* Y X / � B w '. " +. , ,,, . 40 Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the l0 -day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30 -day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). DIO 28 and AEO 11 -EditsperCommissionearman • Subject: DIO 28 and AEO 11 - Edits per Commissioner Norman From: James Regg jim Date: Tue, 07 Dec 2004 12:43:19 -0900 To: jody Womble <jody colomble@achnia' stateAcus5. Attached are edited versions of the 2 orders; these should now be ready for signature. Please fax to Gary Eller at 263-7847 after signature. Jim Jim Regg <jim regg@admin.state.ak.us> 1 Petroleum Engineer AOGCC Content-Type: application/msword AE011edited2004-1207.docl _ _ Content-Encoding: base64 i Content application/msword ID1028 edit 2004-1207.doci _ _ I Content-Encoding: base64 1 of 1 12/7/2004 3:02 PM Orders • • Subject: Orders From: Jody Colombie <jody_colombie @admin.state.ak.us> Date: Tue, 07 Dec 2004 15:36:03 -0900 BCC: <robert� min aw:st t .al :us ;` istitie Hans ' e hansen{ io c .sta ©k.0 , T+ rr e B b le ; : _ <hi bbletl@ ,:corm >, Sondra Stewman <Stew r aSfl a. < 'BP.carn?, SO Ott. 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REA a STA YAN OR, V AMU as low,T. 4, now M A, JAYQ� "tj Q. ww� to, jam, — soty 1 Wow 2' A v got 70 a "Up WINT -5151 ............. WHIM qw 0WAVAG �x ...... ..... logo; ;,Z%qqwYJ,; a A- V yJ WAS' 4 now 4 4• z k, v wnhi nwh ew 0 gA '50 WV n A, NO "K p-SMAR1 All W ova— V T- ghl."& A "8610M " I ?wpm, �_XQJ N "'S"R4 "Tul no 4 wo ill IN n J W", Sm J Ono/, Z MIX A 1gy M, Q-A- -.is 0-0R. OVA 01 my" n, of 2 12/7/2004 4:47 PM • 411 Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102 -6298 Houston, TX 77056 Kelly Valadez Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201 -3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401 -2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045 -0738 Portland, OR 97201 Seattle, WA 98119 -3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Baker Oil Tools Ciri Jill Schneider 4730 Business Park Blvd., #44 Land Department US Geological Survey Anchorage, AK 99503 PO Box 93330 4200 University Dr. Anchorage, AK 99503 Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508 -4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669 -7714 Soldotna, AK 99669 -2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K &K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 Williams Thomas North Slope Borough Arctic Slope Regional Corporation PO Box 69 Land Department Barrow, AK 99723 PO Box 129 ' f Barrow, AK 99723 4i/ /"/7 7 i ' C ? . ci STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7 Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Union Oil ) Disposal Injection Order No. 28A Company of California for disposal ) of Class II oil field wastes by ) Deep Creek Unit underground injection in the Tyonek ) NNA No. 1 Well Formation in the Deep Creek Unit ) NNA No. 1 Well, Section 11, T2S, ) Originally Issued December 7, 2004 R13W, S.M. ) Corrected and Amended June 14, 2005 IT APPEARING THAT: 1. By correspondence to the Alaska Oil and Gas Conservation Commission ( "Commission ") dated October 1, 2004 and received on October 4, 2004, Union Oil Company of California ( "Unocal ") requested authorization to allow the underground injection of non - hazardous Class II oil field waste fluids into the Tyonek Formation within the Deep Creek Unit NNA No. 1 ( "NNA #1 ") well bore. The well is located on the Kenai Peninsula approximately 6 miles east of the city of Ninilchik; 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on October 8, 2004 in accordance with 20 AAC 25.540; 3. The Commission did not receive any protests to the application, comments, or requests for a public hearing; 4. A hearing was held on November 9, 2004, at which Unocal provided sworn testimony addressing engineering and geologic considerations in support of the NNA #1 disposal injection order application. The record was held open to allow Unocal to provide supplemental information about the confining lithologies isolating injected waste fluids from shallow freshwater aquifers as requested by the Commission; and 5. Unocal provided supplemental information addressing fluids eligible for disposal into NNA #1 in a letter dated November 24, 2004. 6. Disposal Injection Order No. 28 was issued on December 7, 2004. 7. The Commission is providing this Disposal Injection Order No. 28A to supersede and replace Disposal Injection Order No. 28, clarifying the fluids authorized for injection. Disposal Injection Order 28A • Page 2 of 7 NNA No. 1 Well June 14, 2005 FINDINGS: 1. Location of adjacent wells (20 AAC 25.252 (c)(1) NNA #1 is a near - vertical well that is located approximately 272 feet from the south line and 510 feet from the west line of Section 11, Township 2 South, Range 13 West, Seward Meridian. There are no wells within 1 /4 mile of NNA #1; 2. Notification of Operators /Surface Owners (20 AAC 25.252 (c)(2) and 20 AAC 25.252 (c)(3)) Unocal is the only operator within 1 /4 mile radius of the proposed disposal operation. The sole surface owner within a 1 /4 mile radius of NNA #1 is Ninilchik Native Association, Inc. Unocal provided evidence that a copy of its application for disposal injection in NNA #1 was sent by certified mail to Ninilchik Native Association, Inc., on October 1, 2004; 3. Geologic information on disposal and confining zones (20 AAC 25.252 (c)(4)) Unocal proposes to conduct disposal into the Tyonek Formation ( "Tyonek ") between the measured depths of 6,182 ft and 9,278 ft. Individual sand intervals within the Tyonek Formation were perforated after drilling to test for natural gas; no commercial gas rates were achieved. Disposal operations in NNA #1 will not impact adjacent production from the Happy Valley field as the nearest development wells are approximately 2 miles away; Geologic information provided by Unocal notes that the Tyonek Formation consists of interbedded conglomerates, sandstones, siltstones, shales and coals deposited in fluvial, lacustrine, alluvial, and terrestrial systems. Sandstones within the proposed disposal interval have estimated porosities up to 22 %, permeabilities in excess of 20 millidarcies, and can approach 40 -ft in thickness (average 20 ft). Unocal has provided evidence that the numerous coal beds ranging in thickness from 6 inches to 30 ft, as well as tight carbonaceous and impervious claystone beds provide vertical confinement for injection into the Tyonek. The Beluga Formation is several thousand feet thick and occurs at depths greater than 2,000 ft in the Deep Creek Unit. This formation is comprised of thinly laminated sandstones, siltstones, shales and coals. Individual sandstone beds within the Beluga Formation are generally less than 30 ft thick, resulting in a heterogeneous sequence of rocks with very poor or no vertical connectivity or permeability. In the area considered for disposal injection, the top of the Beluga Formation is at a depth of approximately 2,400 ft and marked by locally continuous, 75 -ft thick shale. I All depths noted in this Order are measured depth ( "MD ") referenced to NNA #1 and are substantially equivalent to true vertical depth ( "TVD ") below ground level in this near - vertical well. 1 Disposal Injection Order 28A • Page 3 of 7 NNA No. 1 Well June 14, 2005 Supplemental information provided by Unocal on November 17, 2004 identifies more than 1,000 ft of confining lithologies between the aquifer exemption depth (1,800 ft per AEO No. 11) and the depth of uppermost injection perforations (6,182 ft); 4. Well Logs (20 AAC 25.252 (c)(5)) Well logs from NNA #1 are on file with the Commission; 5. Demonstration of Mechanical Integrity and Disposal Zone Isolation (20 AAC 25.252 (c)(6)) Drilling records show that Unocal ran 7" casing and cemented it with 172 - barrel lead and 66- barrel tail cement slurries. An Ultra -Sonic Imaging Tool (USIT) was run in the well 4 days after cementing 7" casing to evaluate the cement sheath in the vicinity of the disposal intervals, focusing specifically on the interval from 5,700 ft to 6,182 ft. Analysis of the USIT results indicates competent cement around the 7" casing below 5,860 ft, isolating the uppermost injection interval with approximately 320 ft of cement. Unocal conducted a successful 3000 -psi mechanical integrity test of the tubing- casing annulus in NNA #1 on August 24, 2004. The pressure test was performed in accordance with 20 AAC 25.412(c); 6. Disposal Fluid Type, Source, Volume and Compatibility with Disposal Zone (20 AAC 25.252 (c)(7)) The primary disposal fluid planned for this well is formation fluid from the Happy Valley Field as well as approved Class II fluids from other Unocal operated fields. Specific wastes include drilling, completion, production, and workover fluids; stimulation fluids and solids; tracer materials; rig wash fluids; glycol dehydration wastes; drilling mud slurries; naturally occurring radioactive material scale slurries; precipitation accumulating within containment areas; tank bottoms; and other fluids brought to surface and generated in connection with oil and gas development activities. Unocal estimates a maximum of 3,000 barrels per day of fluid will be injected in NNA #1; 7. Estimated Injection Pressure (20 AAC 25.252 (c)(8)) , Unocal estimates average surface injection pressure will be 2,200 psig and the maximum surface injection pressure will be 4,000 psig; 2 Maximum injection pressure clarified in public hearing record for DIO 28 (November 9, 2004), pgs 9 -10 • Disposal Injection Order 28A • Page 4 of 7 NNA No. 1 Well June 14, 2005 8. Evaluation of Confining Zones (20 AAC 25.252 (c)(9)) The potential to fracture through the confining lithologies at NNA #1 was modeled by a Unocal consultant. Included in the consultant's analysis was experience from observed behavior of Beluga - Tyonek facture treatments in the region. The goal of this evaluation was to predict the expected upward fracture growth for cuttings disposal at NNA #1 using worst -case assumptions. The simulation assumed continuous 2 -day injection of 8,000 barrels of slurry in 10 equal events separated by 59.5- barrel sweeps with clean fluid. Slurry make -up was assumed to have a 12 percent solids concentration with 30/50 -mesh sand distribution and density of 10 pounds per gallon. Injection rate for the modeling work was 2.5 barrels per minute. Only the uppermost perforated interval (6,182 ft — 6,222 ft) is assumed open. In this worst -case model, the critical factor is vertical fracture propagation, with a critical limit being the log- derived top of cement in the production casing annulus (5,860 ft, or 322 ft above the top of perforations). The fracture analysis indicates that coal intervals overlying the injection interval tend to impede the fracture height growth within the Tyonek Formation. Modeling shows the fracture height is not expected to grow beyond the top of cement. Unocal further notes that the injection assumptions included in the modeling work significantly exceed maximum estimated fluid injection per day; 9. Standard Laboratory Water Analysis of the Disposal Zone (20 AAC 25.252 (c)(10)) A laboratory analysis of formation water sampled from one of the Tyonek sands in NNA #1 identified total dissolved solids greater than 7,000 ppm; 10. Aquifer Exemption (20 AAC 25.252 (c)(11)) Pursuant to a separate proceeding, an aquifer exemption has been granted, in Aquifer Exemption Order No. 11, for depths greater than 1,800 ft covering 3 specific areas within the Deep Creek Unit: - A 1 /4 mile radius around NNA #1; - All of Section 22, which includes the Happy Valley pad and associated wells; - The southeast one - quarter of Section 15; and - All of Section 21, which will cover a new drillsite and associated wells planned by Unocal for the Deep Creek Unit; and 11. Mechanical Condition of Wells Penetrating the Disposal Zone within 1 /4 Mile of NNA #1 (20 AAC 25.252 (c)(12) There are no wells penetrating the disposal zone within 1 A mile radius of NNA #1. • D 1 isposal Injection Order 28A Page 5 of 7 NNA No. 1 Well June 14, 2005 CONCLUSIONS: 1. The application requirements of 20 AAC 25.252(c) have been met; 2. Mechanical integrity of the tubing- casing annulus to a depth of 6,097 ft has been demonstrated in NNA #1 by pressure test. Competent cement has been demonstrated in the casing annulus to 5,860 ft. NNA #1 has been cased and the casing cemented in a manner that will isolate the disposal zone and protect oil, gas, and freshwater sources; 3. At NNA #1, there are approximately 180 ft of confining lithologies between the top of cement in the 7" casing annulus and the uppermost perforations. While other confining lithologies are documented, the Commission does not recognize these as effective confining zones since the uncemented annulus above 5,860 ft provides a communication path for fluid migration up hole should the 180 -ft net thickness be compromised; 4. Worst -case fracture modeling confirms that waste fluids will be contained within the receiving intervals by the confining lithologies within the Tyonek Formation, cement isolation of the well bore and operating conditions; 5. Disposal injection operations in NNA #1 will be conducted at rates and pressures below those estimated to fracture through the confining zones. Therefore, oil field wastes will not enter freshwater strata; and 6. Supplemental mechanical integrity demonstrations and surveillance of injection operations are appropriate to ensure waste fluids are contained within the disposal interval. Included are mechanical integrity testing, temperature surveys, monitoring of injection performance (pressures, rates), and analysis of the data for indications of anomalous events. NOW, THEREFORE, IT IS ORDERED THAT this Disposal Injection Order No. 28A supersedes Disposal Injection Order No. 28, and that the following rules are adopted: RULE 1: Authorized Injection Strata for Disposal Injection of authorized fluids for purposes of underground disposal of oil field wastes is permitted into the Tyonek Formation below 6,000 ft in NNA #1. The Commission may immediately suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated injection strata. RULE 2: Authorized Fluids This authorization is limited only to Class II waste fluids as follow: produced water, drilling, completion, production and work over fluids (including stimulation fluids and solids, and tracer materials), rig wash, drilling mud slurries, NORM scale, precipitation • Disposal Injection Order 28A Page 6 of 7 NNA No. 1 Well June 14, 2005 accumulating within containment areas, tank bottoms, and glycol dehydration wastes. The Commission may authorize the disposal of additional fluids not identified above on a case -by -case basis if the Commission determines they are suitable for disposal in a Class II well. RULE 3: Demonstration of Mechanical Integrity The mechanical integrity of NNA #1 must be demonstrated before injection begins, and before returning a well to service following a workover affecting mechanical integrity. A Commission - witnessed mechanical integrity test must be performed after injection is commenced for the first time in NNA #1, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Subsequent tests must be performed at least once every four years thereafter except at least once every two years in the case of a slurry injection well. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing /casing annulus pressure test using a surface pressure of 1,500 psi or 0.25 psi /ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. Results of mechanical integrity tests must be readily available for Commission inspection. RULE 4: Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall notify the Commission by the next business day and submit a plan of corrective action on a Form 10 -403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission indicating well integrity failure or lack of injection zone isolation. RULE 5: Surveillance The operator shall obtain a baseline temperature log and a baseline step rate test prior to initial injection. A subsequent temperature log must be performed 1 month after injection begins to demonstrate the receiving zone of the injected fluids. Additional temperature survey requirements will be based on the results of the initial and follow -up temperature surveys. An annual report for the calendar year evaluating the performance of the disposal operation must be submitted by July 1 of each year. The report shall include pressures, fluid volumes (disposal and clean fluid sweeps), fluid make -up, injection rates, an assessment of fracture height growth, and a description of any anomalous injection results. During the first year of injection, a monthly evaluation of injection monitoring results must be provided to the Commission with an emphasis on fracture height growth. • Disposal Injection Order 28A • Page 7 of 7 NNA No. 1 Well June 14, 2005 RULE 6: Notification of Improper Class II Injection The operator must immediately notify the Commission if it learns of any improper Class II injection. Additionally, notification requirements of any other State or Federal agency remain the operators' responsibility. RULE 7: Administrative Action Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. RULE 8: Conditions It is a condition of this authorization that operations be conducted in accordance with the rules set out in this order, with AS 31.05, and (unless specifically superseded by Commission order) with 20 AAC 25. Failure to comply with an applicable provision of AS 31.05, 20 AAC 25, or these rules may result in the suspension or revocation of this authorization. DONE at Anchorage, Alaska and dated J 1 4 11 OIL I. IL "►`d I r ' . Nor ! , ChairmMIIIII '4 1------- . 7 -,,--- n ' f ,0 i , K - : , Daniel T. Seamount, Jr., Commissioner n 9 ' 7 3+ P i l� - - ' - ....t./..„ ,a/ /Ars( ?I OjS CO Cathy ' . Foers er, Commissioner AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10 -day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30 -day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). i Amended Orders Cook Inlet and Admin Approv edoubt Subject: Amended Orders Cook Inlet and Admin Approval Redoubt From: Jody Colombie < jody _colombie @admin.state.ak.us> Date: Wed, 15 Jun 2005 11:30:50 -0800 To: undisclosed- recipients:; BCC: Robert E Mintz <robert_mintz @law.state.ak.us >, Christine Hansen <c.hansen @iogcc.state.ok.us >, Terrie Hubble <hubbletl @bp.com >, Sondra Stewman <StewmaSD @BP.com >, Scott & Cammy Taylor <staylor @alaska.net >, stanekj <stanekj @unocal.com >, ecolaw <ecolaw @trustees.org >, roseragsdale <roseragsdale @gci.net >, trmjrl <trmjr1 @aol.com >, jbriddle <jbriddle @marathonoil.com >, shaneg <shaneg @evergreengas.com >, jdarlington <jdarlington @forestoil.com >, nelson <knelson @petroleumnews.com >, cboddy <cboddy @usibelli.com >, Mark Dalton <mark.dalton @hdrinc.com >, Shannon Donnelly < shannon .donnelly @conocophillips.com >, "Mark P. Worcester" < mark. p .worcester @conocophillips.com >, Bob <bob @inletkeeper.org >, wdv <wdv @dnr.state.ak.us >, tjr <tjr @dnr.state.ak.us >, bbritch <bbritch @alaska.net >, mjnelson <mjnelson @purvingertz.com >, Charles O'Donnell <charles.o'donnell @veco.com >, "Randy L. Skillern" <SkilleRL @BP.com >, "Deborah J. Jones" <JonesD6 @BP.com >, , "Steven R. Rossberg" <RossbeRS @BP.com >, Lois <lois @inletkeeper.org >, Dan Bross <kuacnews @kuac.org >, Gordon Pospisil <PospisG @BP.com >, "Francis S. Sommer" <SommerFS @BP.com >, Mikel Schultz <Mikel.Schultz @BP.com >, "Nick W. Glover" <GloverNW @BP.com >, "Daryl J. Kleppin" <KleppiDE @BP.com >, "Janet D. Platt" <PlattJD @BP.com >, "Rosanne M. Jacobsen" <JacobsRM @BP.com >, ddonkel <ddonkel @cfl.rr.com >, mckay <mckay @gci.net >, Barbara F Fullmer < barbara .£fullmer @conocophillips.com >, bocastwf <bocastwf @bp.com >, Charles Barker <barker @usgs.gov >, doug_schultze <doug_schultze @xtoenergy.com >, Hank Alford <hank.alford @exxonmobil.com >, Mark Kovac <yesnol @gci.net >, gspfoff <gspfoff @aurorapower.com >, Gregg Nady <gregg.nady @shell.com >, Fred Steece <fred.steece @state.sd.us >, rcrotty <rcrotty@ch2m.com >, jejones <jejones @aurorapower.com >, dapa <dapa @alaska.net>, jroderick <jroderick @gci.net >, eyancy <eyancy @seal- tite.net>, "James M. Ruud" < james .m.ruud @conocophillips.com >, Brit Lively <mapalaska @ak.net >, jah <jah @dnr.state.ak.us >, Kurt E Olson <kurt_olson @legis.state.ak.us >, buonoje <buonoje @bp.com >, Mark Hanley <mark_hanley @anadarko.com >, loren_leman <loren_leman @gov.state.ak.us >, Julie Houle <julie_houle @dnr.state.ak.us >, John W Katz <jwkatz @sso.org >, Suzan J Hill <suzan_hill @dec.state.ak.us >, tablerk <tablerk @unocal.com >, Brady <brady @aoga.org >, Brian Havelock <beh @dnr.state.ak.us >, bpopp <bpopp @borough.kenai.ak.us >, Jim White <jimwhite @satx.rr.com >, "John S. Haworth" <john.s.haworth @exxonmobil.com >, marry <marty @rkindustrial.com >, ghammons <ghammons @aol.com >, rmclean <rmclean@pobox.alaska.net >, mkm7200 <mkm7200 @aol.com >, Brian Gillespie <ifbmg @uaa.alaska.edu >, David L Boelens <dboelens @aurorapower.com >, Todd Durkee <TDURKEE @KMG.com >, Gary Schultz <gary_schultz @dnr.state.ak.us >, Wayne Rancier <RANCIER @petro- canada.ca >, Bill Miller <BillMiller @xtoalaska.com >, Brandon Gagnon <bgagnon @brenalaw.com >, Paul Winslow <pmwinslow @forestoil.com >, Garry Catron <catrongr @bp.com >, Sharmaine Copeland <copelasv @bp.com >, Kristin Dirks <kristin_dirks @dnr.state.ak.us >, Kaynell Zeman <kjzeman @marathonoil.com >, John Tower <John.Tower @eia.doe.gov >, Bill Fowler <Bill_Fowler @anadarko.COM >, Vaughn Swartz <vaughn.swartz @rbccm.com >, Scott Cranswick <scott.cranswick @mms.gov >, Brad McKim <mckimbs @BP.com >, Steve Lambe <lambes @unocal.com >, jack newell <jack.newell @acsalaska.net >, James Scherr <james_scherr @yahoo.com >, david roby <David.Roby @mms.gov >, Tim Lawlor of 2 6/15/2005 11:31 AM Amended Orders Cook Inlet and Admin Appro edoubt • <Tim_Lawlor @ak.blm.gov >, Lynnda Kahn <Lynnda_Kahn @fws.gov >, Jerry Dethlefs <Jerry.C.Dethlefs @conocophillips.com >, Jerry Dethlefs <n1617 @conocophillips.com >, crockett @aoga.org, Tamera Sheffield <sheffield @aoga.org >, Jon Goltz <Jon.Goltz @conocophillips.com >, Roger Belman < roger .belman@conocophillips.com >, Mindy Lewis <mlewis @brenalaw.com >, Harry Lampert <harry.lampert@honeywell.com >, Kari Moriarty <moriarty @aoga.org >, Patty Alfaro <palfaro @yahoo.com >, Cynthia B Mciver <bren mciver @admin.state.ak.us> Content -Type: application/pdf ER02.001.pdf Content - Encoding: base64 Content -Type: application/pdf DI030A.pdf Content- Encoding: base64 Content -Type: application/pdf DIO28A.pdf Content- Encoding: base64 2 of 2 6/15/2005 11:31 AM • • Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102 -6298 Houston, TX 77056 Mona Dickens Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201 -3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401 -2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045 -0738 Portland, OR 97201 Seattle, WA 98119 -3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr. #5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508 -4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669 -2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669 -7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl Williams Thomas North Slope Borough K &K Recycling Inc. Arctic Slope Regional Corporation PO Box 69 PO Box 58055 Land Department Barrow, AK 99723 Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 ga/% 6 / / s��� INDEXES N T Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 21, 2010 3:25 PM To: 'O'Brien - Authier , Erin C. [PRA]' r l Cc: Whitacre, Dave S; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)]; Greenstein, Larry P Subject: RE: NNA #1 (201 -215) Delinquent Annual Reports Thank you. That answers my question. Tom Maunder, PE AOGCC From: O'Brien - Authier , Erin C. [PRA] [mailto:EODM @chevron.com] Sent: Tuesday, December 21, 2010 3:23 PM To: Maunder, Thomas E (DOA) Cc: Whitacre, Dave S; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)]; Greenstein, Larry P Subject: RE: NNA #1 (201 -215) Delinquent Annual Reports Tom, In response to your question below about the source and need for pressure on the 7" casing in NNA #1. Prior to September 2009, the 7" casing pressure was measured as follows: The 7" casing pressure was initially at 100psig and would decrease to 0 psig within 90 minutes of an injection cycle due to cooling (pumping cooler, 50 degree water). When at 0 psig, the operators couldn't differentiate between a true 0 psig reading or having the well on a vacuum. Raising the casing pressure to approximately 500 psig allows the operators to track pressures during the entire injection cycle. This has been done since September 2009, and is the operational change referenced on the graph. If you have any other questions, please don't hesitate to call or email. Thanks, I I From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, December 16, 2010 1:26 PM To: O'Brien - Authier , Erin C. [PRA] Cc: Whitacre, Dave S Subject: NNA #1 (201 -215) Delinquent Annual Reports Erin, I have examined the delinquent reports for 2008 (17 months late) and 2009 (5 months late) recently submitted to the Commission. did not find anything of note in the 2008 report. In the 2009 report, the inner annulus pressure increases to —500 psi in September and remains there. There is a comment "operational change allows casing pressure to stabilize at —480 psi". I have not located any corrospondance /messages from Unocal /Chevron regarding the IA pressure increase. Please provide information regarding the source and need for annulus pressure. Thanks in advance, Tom Maunder, PE AOGCC 12/23/2010 V"' Regg, James B (DOA) • • From: Regg, James B (DOA) Sent: Monday, November 26, 2007 2:21 PM (R otzei 417-‘ To: 'Bodeau, Jean' Cc: Maunder, Thomas E (DOA); Foerster, Catherine P (DOA) Subject: RE: Request to dispose precipitation in NNA -1 (DIO28) Attachments: DIO28A_NNA -1.pdf DIO 28A (NNA -1) was amended June 14, 2005 to include "precipitation accumulating within containment areas" (copy attached; refer to Rule 2). No additional action is necessary. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907- 793 -1236 fax: 907 - 276 -7542 From: Maunder, Thomas E (DOA) Sent: Monday, November 26, 2007 10:27 AM To: Regg, James B (DOA) Subject: FW: Request to dispose precipitation in NNA -1 (DIO28) From: Bodeau, Jean [mailto:BodeauJ @chevron.com] Sent: Monday, November 26, 2007 9:58 AM To: Maunder, Thomas E (DOA) Subject: Request to dispose precipitation in NNA -1 (DIO28) Dear Mr. Maunder, I am writing to request authorization to dispose precipitation collected from lined, bermed secondary containment areas into NNA -1 (DIO 28) near Happy Valley. The attached letter contains more details. Thank you very much for your assistance. «NNA1 DIO28.pdf» Jean Jean M. Bodeau, CPG Hydrogeologist Waste Specialist Chevron North America Exploration and Production Company P.O. Box 196247 Anchorage, AK 99519 -6247 Tel. (907) 263 -7308 Fax (907) 263 -7321 Mobile (907) 360 -7929 BodeauJ @chevron.com 11/26/2007 • • Chevron Jean Bodeau, CPG Chevron North America '� Flydrogeologist Exploration and Production x Waste Specialist 909 West 9 Avenue aig. p p P.O. Box 196247 Anchorage, AK 99519 -6247 Tel 907 263 7308 Fax 907 263 7321 Cell 907 360 7929 Email Bodeau] @chevron.com November 26, 2007 Mr. Thomas Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 RE: REQUEST FOR OPINION ON DIO 28 FOR DEEP CREEK UNIT NNA NO. 1 WELL Dear Mr. Maunder: Disposal Injection Order No. DIO 28, issued by AOGCC on December 7, 2004, authorized Union Oil Company of California to perform disposal injection of Class II oil field waste fluids into the Tyonek Formation within the Deep Creek Unit NNA -1 well. The fluids approved under DIO 28 include drilling, completion, production, and workover fluids; stimulation fluids and solids; tracer materials; rig wash fluids; glycol dehydration waste; drilling mud slurries; naturally occurring radioactive material scale slurries; tank bottoms; and other fluids brought to the surface and generated in connection with oil and gas development activities at Happy Valley and other "Unocal " - operated fields. I am writing to request approval to dispose precipitation collected from bermed secondary containment areas associated with exploration and development at Happy Valley, such as those around the drill rig, the NNA -1 G &I facility, drilling material storage areas, production material storage areas, and well cellars. Please contact me at (907) 263 -7308 or by email at bodeaujAchevron.com if you require additional information. Thank you very much for your consideration and assistance. Best regards, Digitally awed by Jean Bodeau Jean Bodeau D Cnev an =MCA =U6 o=C llaB ou =MCA ma od ll = 007 11 X 0 oom 09 55 Dale 200711.2609'5501-09'00' Jean Bodeau Waste Specialist Midcontinent /Alaska SBU /Chevron North America Exploration and Production http: / /www.chevron.com • Bcc: Mr. Greg Merle, Chevron Mr. Evan Harness, Chevron Mr. Larry Greenstein, Chevron ■ 0 r 4 410 • AOGCC Memorandum Date: July 16, 2007 To: DIO 28A -7 From: Jim Regg, Petroleum Engineer C� Subject: Annual Disposal Injection Performance Report Chevron submitted the 2006 Deep Creek Unit ( "DCU ") Annual Disposal Injection Performance Report on June 27, 2007 as required by Disposal Injection Order ( "DIO ") 28A, Rule 5 and 20 AAC 25.432. The report covers Class II disposal injection at the NNA #1 well proximate to the Happy Valley field. Primary source of fluid injection is produced water from Happy Valley wells. I have completed a review of the disposal injection performance report and find it to be complete. Based on the performance data provided, I concur with the findings of Chevron that there is no indication of any reservoir or mechanical concerns with the ongoing disposal injection operations. Data presented indicates fluids are confined to the intended injection zone. Injection performance is consistent with Commission findings, conclusions and approved conditions in DIO 28A. Monitoring of NNA #1 disposal operations should continue as directed in DIO 28A. , I CZ VF Annual Disposal Reports Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8300 Fax: 907-777-8580 March 31, 2025 Mr. Chris Wallace, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2024 Annual Disposal Report for Deep Creek Unit, Deep Creek NNA 1 (DIO 28A) Dear Mr. Wallace: In accordance with DIO 28A (Rule 5), Hilcorp Alaska, LLC hereby submits the annual disposal report for Deep Creek NNA 1 (PTD # 201-215) for the year 2024. Surveillance Summary Deep Creek NNA 1 was used for disposal operations in 2024. Injection and annuli pressures [see attached] indicate no reservoir or mechanical concerns. All indications from the injection rates and pressures are that the injected fluid is contained to the approved disposal zone. Specific items to note for this reporting period: x The fluids injected into the NNA 1 were composed of produced water, pad dewatering, and authorized fluids from neighboring Hilcorp operated leases. x A passing MIT was performed in May of 2023. x The average injection pressure in 2024 was approximately 2,437 psig. x The maximum injection pressure in 2024 was 2,850 psig which is below the permitted 4,000 psig maximum injection pressure. x Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 2.5 BPM (3600 bpd) of a slurry laden fluid. In contrast, the well injection volumes during 2024 were no more than 952 BPD. Should you have questions, please contact Joleen Oshiro at 777-8486. Sincerely, Joleen Oshiro Reservoir Engineer Digitally signed by Joleen Oshiro (4381) DN: cn=Joleen Oshiro (4381) Date: 2025.03.31 10:52:03 - 08'00' Joleen Oshiro (4381) Date Water Injection (BWPD) Tubing Pre Casing Pressure (psig) 12/31/2024 720 2250 265 12/30/2024 699 2250 300 12/29/2024 611 2250 300 12/28/2024 790 2300 300 12/27/2024 760 2300 290 12/26/2024 657 2250 310 12/25/2024 625 2250 340 12/24/2024 868 2300 325 12/23/2024 572 2320 345 12/22/2024 875 2225 255 12/21/2024 392 2250 355 12/20/2024 2100 90 12/19/2024 2100 90 12/18/2024 2100 90 12/17/2024 520 2300 315 12/16/2024 740 2300 300 12/15/2024 660 2250 320 12/14/2024 659 2300 345 12/13/2024 725 2210 330 12/12/2024 612 2250 285 12/11/2024 790 2225 290 12/10/2024 420 2225 360 12/9/2024 540 2225 350 12/8/2024 690 2275 315 12/7/2024 862 2250 280 12/6/2024 439 2200 355 12/5/2024 367 2300 345 12/4/2024 640 2300 300 12/3/2024 767 2300 260 12/2/2024 563 2300 260 12/1/2024 540 2300 280 11/30/2024 615 2300 280 11/29/2024 615 2300 290 11/28/2024 540 2300 300 11/27/2024 720 2300 300 11/26/2024 690 2300 320 11/25/2024 662 2300 310 11/24/2024 543 2300 310 11/23/2024 685 2300 300 11/22/2024 600 2300 290 11/21/2024 706 2250 290 11/20/2024 680 2200 295 11/19/2024 650 2225 305 11/18/2024 685 2200 315 11/17/2024 540 2250 310 11/16/2024 720 2250 315 11/15/2024 560 2225 280 11/14/2024 791.7 2250 290 11/13/2024 717 2250 310 11/12/2024 645 2235 325 11/11/2024 712 2200 350 11/10/2024 560 2175 335 11/9/2024 710 2275 350 11/8/2024 585 2225 250 11/7/2024 691 2300 230 11/6/2024 655 2300 220 11/5/2024 665 2300 220 11/4/2024 665 2300 220 11/3/2024 665 2300 220 11/2/2024 665 2300 250 11/1/2024 450 2300 250 10/31/2024 625 2300 300 10/30/2024 766 2350 350 10/29/2024 697 2325 325 10/28/2024 553 2350 360 10/27/2024 686 2400 340 10/26/2024 609 2350 330 10/25/2024 640 2350 340 10/24/2024 660 2350 355 10/23/2024 650 2300 360 10/22/2024 600 2300 360 10/21/2024 600 2300 365 10/20/2024 580 2250 330 10/19/2024 190 2200 200 10/18/2024 10/17/2024 270 2200 350 10/16/2024 650 2300 360 10/15/2024 695 2350 315 10/14/2024 815 2325 310 10/13/2024 636 2300 300 10/12/2024 634 2200 345 10/11/2024 670 2225 350 10/10/2024 750 2200 360 10/9/2024 590 2400 365 10/8/2024 700 2400 360 10/7/2024 690 2300 350 10/6/2024 690 2200 370 10/5/2024 695 2200 355 10/4/2024 700 2200 370 10/3/2024 738 2200 375 10/2/2024 702 2200 380 10/1/2024 657 2200 385 9/30/2024 767 2200 360 9/29/2024 683 2200 375 9/28/2024 670 2200 345 9/27/2024 642 2275 325 9/26/2024 932 2250 380 9/25/2024 690 2200 380 9/24/2024 690 2200 390 9/23/2024 2200 370 9/22/2024 2200 370 9/21/2024 2200 370 9/20/2024 2200 370 9/19/2024 700 2200 370 9/18/2024 680 2200 375 9/17/2024 621 2175 390 9/16/2024 634 2175 405 9/15/2024 535 2200 390 9/14/2024 666 2175 395 9/13/2024 657 2150 400 9/12/2024 572 2100 380 9/11/2024 2200 270 9/10/2024 2200 270 9/9/2024 2200 270 9/8/2024 140 2200 270 9/7/2024 695 2200 390 9/6/2024 480 2200 380 9/5/2024 647 2300 385 9/4/2024 766 2200 360 9/3/2024 567 2200 390 9/2/2024 620 2200 380 9/1/2024 547 2200 390 8/31/2024 668 2200 375 8/30/2024 498 2200 385 8/29/2024 727 2300 380 8/28/2024 674 2300 375 8/27/2024 750 2300 380 8/26/2024 685 2300 380 8/25/2024 675 2300 375 8/24/2024 730 2300 395 8/23/2024 694 2300 375 8/22/2024 634 2300 385 8/21/2024 660 2300 380 8/20/2024 662 2300 385 8/19/2024 726 2300 380 8/18/2024 698 2300 390 8/17/2024 706 2300 385 8/16/2024 710 2300 370 8/15/2024 615 2325 385 8/14/2024 710 2300 385 8/13/2024 735 2300 360 8/12/2024 640 2275 385 8/11/2024 520 2250 375 8/10/2024 757 2300 375 8/9/2024 626 2250 370 8/8/2024 577 2250 400 8/7/2024 2300 415 8/6/2024 704 2300 390 8/5/2024 668 2275 395 8/4/2024 613 2300 405 8/3/2024 682 2300 385 8/2/2024 663 2275 390 8/1/2024 592 2300 400 7/31/2024 700 2300 380 7/30/2024 600 2300 385 7/29/2024 613 2300 390 7/28/2024 617 2300 400 7/27/2024 573 2300 400 7/26/2024 682 2300 385 7/25/2024 530 2300 410 7/24/2024 705 2300 405 7/23/2024 573 2300 400 7/22/2024 477 2325 405 7/21/2024 917 2325 310 7/20/2024 596 2300 350 7/19/2024 555 2325 330 7/18/2024 814 2300 270 7/17/2024 468 2300 385 7/16/2024 825 2300 290 7/15/2024 560 2300 380 7/14/2024 820 2300 390 7/13/2024 410 2300 390 7/12/2024 594 2300 390 7/11/2024 616 2325 360 7/10/2024 467 2325 325 7/9/2024 626 2325 400 7/8/2024 464 2325 405 7/7/2024 453 2325 403 7/6/2024 525 2340 335 7/5/2024 765 2350 295 7/4/2024 505 2300 395 7/3/2024 565 2300 390 7/2/2024 525 2300 390 7/1/2024 597 2300 390 6/30/2024 643 2300 390 6/29/2024 549 2315 380 6/28/2024 366 2300 310 6/27/2024 640 2340 310 6/26/2024 376 2690 340 6/25/2024 539 2375 360 6/24/2024 798 2375 350 6/23/2024 483 2375 360 6/22/2024 791 2350 350 6/21/2024 446 2300 365 6/20/2024 497 2350 365 6/19/2024 580 2400 350 6/18/2024 410 2300 370 6/17/2024 660 2400 330 6/16/2024 795 2400 370 6/15/2024 652 2400 340 6/14/2024 648 2400 340 6/13/2024 515 2325 290 6/12/2024 847 2425 300 6/11/2024 688 2400 320 6/10/2024 678 2400 320 6/9/2024 695 2400 345 6/8/2024 507 2450 320 6/7/2024 602 2400 348 6/6/2024 456 2500 380 6/5/2024 694 2500 355 6/4/2024 408 2500 340 6/3/2024 885 2500 280 6/2/2024 629 2500 370 6/1/2024 871 2500 330 5/31/2024 850 2500 280 5/30/2024 500 2400 320 5/29/2024 495 2400 330 5/28/2024 820 2400 340 5/27/2024 440 2400 320 5/26/2024 655 2400 340 5/25/2024 735 2400 320 5/24/2024 532 2400 365 5/23/2024 578 2550 320 5/22/2024 563 2500 285 5/21/2024 580 2525 310 5/20/2024 617 2500 355 5/19/2024 527 2450 375 5/18/2024 435 2400 305 5/17/2024 683 2500 250 5/16/2024 525 2400 300 5/15/2024 848 2450 265 5/14/2024 520 2450 356 5/13/2024 499 2500 360 5/12/2024 473 2500 365 5/11/2024 640 2500 350 5/10/2024 433 2450 370 5/9/2024 552 2450 350 5/8/2024 750 2450 240 5/7/2024 480 2450 360 5/6/2024 502 2450 350 5/5/2024 668 2600 340 5/4/2024 483 2600 370 5/3/2024 460 2500 360 5/2/2024 510 2450 310 5/1/2024 442 2475 360 4/30/2024 695 2450 250 4/29/2024 201 2425 370 4/28/2024 782 2475 290 4/27/2024 549 2475 350 4/26/2024 413 2500 365 4/25/2024 428 2500 350 4/24/2024 562 2600 350 4/23/2024 329 2600 350 4/22/2024 648 2600 200 4/21/2024 454 2700 345 4/20/2024 396 2700 350 4/19/2024 801 2650 100 4/18/2024 313 2600 355 4/17/2024 522 2575 350 4/16/2024 458 2525 350 4/15/2024 478 2595 330 4/14/2024 417 2575 340 4/13/2024 390 2600 330 4/12/2024 821 2600 165 4/11/2024 509 2700 330 4/10/2024 480 2700 340 4/9/2024 609 2700 103 4/8/2024 570 2700 325 4/7/2024 604 2700 350 4/6/2024 490 2650 340 4/5/2024 445 2650 345 4/4/2024 307 2775 340 4/3/2024 822 2750 150 4/2/2024 439 2725 345 4/1/2024 417 2750 350 3/31/2024 515 2725 280 3/30/2024 610 2725 335 3/29/2024 287 2725 350 3/28/2024 920 2750 365 3/27/2024 485 2700 340 3/26/2024 505 2800 335 3/25/2024 622 2800 330 3/24/2024 536 2800 330 3/23/2024 446 2800 350 3/22/2024 428 2800 320 3/21/2024 749 2800 270 3/20/2024 591 2750 315 3/19/2024 465 2775 310 3/18/2024 832 2750 135 3/17/2024 498 2750 325 3/16/2024 437 2775 160 3/15/2024 578 2750 300 3/14/2024 414 2800 315 3/13/2024 682 2800 100 3/12/2024 552 2800 100 3/11/2024 952 2800 110 3/10/2024 495 2800 310 3/9/2024 539 2800 320 3/8/2024 533 2800 290 3/7/2024 424 2800 330 3/6/2024 564 2800 275 3/5/2024 838 2750 295 3/4/2024 468 2750 290 3/3/2024 590 2750 270 3/2/2024 485 2775 300 3/1/2024 338 2800 315 2/29/2024 587 2750 330 2/28/2024 450 2700 330 2/27/2024 500 2700 330 2/26/2024 455 2700 345 2/25/2024 385 2700 280 2/24/2024 545 2700 280 2/23/2024 487 2700 345 2/22/2024 318 2700 375 2/21/2024 445 2725 370 2/20/2024 340 2650 365 2/19/2024 643 2700 220 2/18/2024 369 2700 355 2/17/2024 298 2700 370 2/16/2024 472 2750 215 2/15/2024 565 2700 350 2/14/2024 452 2700 345 2/13/2024 447 2700 330 2/12/2024 471 2700 325 2/11/2024 597 2700 320 2/10/2024 404 2700 335 2/9/2024 332 2650 320 2/8/2024 450 2700 320 2/7/2024 479 2700 320 2/6/2024 411 2800 280 2/5/2024 405 2850 300 2/4/2024 383 2725 305 2/3/2024 324 2700 305 2/2/2024 330 2850 300 2/1/2024 243 2650 315 1/31/2024 300 2700 280 1/30/2024 447 2800 280 1/29/2024 359 2800 290 1/28/2024 468 2800 290 1/27/2024 468 2800 290 1/26/2024 464 2800 300 1/25/2024 472 2800 310 1/24/2024 363 2700 330 1/23/2024 372 2800 320 1/22/2024 454 2800 320 1/21/2024 447 2800 330 1/20/2024 462 2700 340 1/19/2024 453 2700 330 1/18/2024 448 2700 350 1/17/2024 350 2525 340 1/16/2024 490 2675 325 1/15/2024 562 2675 375 1/14/2024 403 2650 350 1/13/2024 445 2525 430 1/12/2024 1/11/2024 102 2500 345 1/10/2024 340 2550 335 1/9/2024 480 2625 355 1/8/2024 361 2600 340 1/7/2024 437 2625 330 1/6/2024 504 2600 350 1/5/2024 393 2600 335 1/4/2024 618 2625 295 1/3/2024 420 2700 330 1/2/2024 395 2700 335 1/1/2024 408 2700 290 Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8300 Fax: 907-777-8580 June 30, 2024 Mr. Chris Wallace, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2023 Annual Disposal Report for Deep Creek Unit, Deep Creek NNA 1 (DIO 28A) Dear Mr. Wallace: In accordance with DIO 28A (Rule 5), Hilcorp Alaska, LLC hereby submits the annual disposal report for Deep Creek NNA 1 (PTD # 201-215) for the year 2023. Surveillance Summary Deep Creek NNA 1 was used for disposal operations in 2023. Injection and annuli pressures [see attached] indicate no reservoir or mechanical concerns. All indications from the injection rates and pressures are that the injected fluid is contained to the approved disposal zone. Specific items to note for this reporting period: The fluids injected into the NNA 1 were composed of produced water, pad dewatering, and authorized fluids from neighboring Hilcorp operated leases. A passing MIT was performed in May of 2023. The average injection pressure in 2023 was approximately 2,542 psig. The maximum injection pressure in 2023 was 3,200 psig which is below the permitted 4,000 psig maximum injection pressure. Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 2.5 BPM (3600 bpd) of a slurry laden fluid. In contrast, the well injection volumes during 2023 were no more than 645 BPD. Should you have questions, please contact Casey Morse at 777-8322. Sincerely, Casey Morse Well Integrity Engineer Date Tubing IA OA Water Injection 1/1/2024 2700 290 101 408 12/31/2023 2700 300 103 504 12/30/2023 2700 300 103 502 12/29/2023 2700 315 103 496 12/28/2023 2600 585 12/27/2023 2400 350 105 516 12/26/2023 2600 340 105 369 12/25/2023 2625 355 105 537 12/24/2023 2600 155 110 433 12/23/2023 2600 150 105 413 12/22/2023 2750 325 105 0 12/21/2023 2750 325 105 494 12/20/2023 2700 345 104 464 12/19/2023 2700 330 103 446 12/18/2023 2700 340 104 451 12/17/2023 2700 330 102 449 12/16/2023 2700 320 102 462 12/15/2023 2700 320 103 358 12/14/2023 2700 320 104 457 12/13/2023 2750 360 105 572 12/12/2023 2775 405 105 645 12/11/2023 2750 350 104 143 12/10/2023 2700 190 104 455 12/9/2023 2375 355 105 0 12/8/2023 2375 350 105 73 12/7/2023 2725 340 105 363 12/6/2023 2700 350 105 469 12/5/2023 2700 335 104 302 12/4/2023 2700 350 103 440 12/3/2023 2700 360 105 415 12/2/2023 2700 365 104 470 12/1/2023 2600 380 104 445 11/30/2023 2600 370 103 332 11/29/2023 2750 375 105 490 11/28/2023 2775 375 105 330 11/27/2023 2750 350 105 315 11/26/2023 2700 365 105 360 11/25/2023 2725 380 105 466 11/24/2023 2750 350 105 368 11/23/2023 2750 330 105 298 11/22/2023 2600 350 101 470 11/21/2023 2600 350 103 555 11/20/2023 2600 330 103 397 11/19/2023 2600 375 103 440 11/18/2023 2600 350 103 380 11/17/2023 2600 370 103 446 11/16/2023 2600 360 103 290 11/15/2023 2750 390 105 580 11/14/2023 2750 365 105 300 11/13/2023 2700 390 105 446 11/12/2023 2750 375 105 384 11/11/2023 2725 350 105 345 11/10/2023 2750 390 105 450 11/9/2023 2750 390 105 347 11/8/2023 2600 380 105 460 11/7/2023 2600 400 105 460 Date Range: 01/01/2023 - 01/01/2024 Well: NNA #1 Desc: Disposal Permit to drill: 2012150 Admin Approval: DIO #28A API: 50-133-20507-00-00 11/6/2023 2600 425 105 541 11/5/2023 2500 430 105 267 11/4/2023 2450 430 105 463 11/3/2023 2400 460 105 323 11/2/2023 2300 460 105 223 11/1/2023 2450 410 105 144 10/31/2023 2700 440 106 290 10/30/2023 2700 450 105 330 10/29/2023 2625 450 105 185 10/28/2023 2625 440 105 265 10/27/2023 2700 465 105 320 10/26/2023 2550 440 105 170 10/25/2023 2650 450 125 318 10/24/2023 2650 450 105 152 10/23/2023 2675 460 105 355 10/22/2023 2600 460 105 260 10/21/2023 2650 470 105 208 10/20/2023 2600 470 105 199 10/19/2023 2650 460 105 178 10/18/2023 2500 470 104 259 10/17/2023 2700 470 104 223 10/16/2023 2700 440 104 174 10/15/2023 2700 460 105 299 10/14/2023 2700 450 105 231 10/13/2023 2650 450 105 81 10/12/2023 2700 450 105 270 10/11/2023 2750 460 105 335 10/10/2023 2700 460 105 225 10/9/2023 2700 440 105 131 10/8/2023 2800 440 105 343 10/7/2023 2700 430 103 199 10/6/2023 2800 400 105 328 10/5/2023 2850 440 105 467 10/4/2023 2700 415 105 255 10/3/2023 2750 390 105 345 10/2/2023 2750 420 107 525 10/1/2023 2750 405 105 375 9/30/2023 2750 425 105 478 9/29/2023 2725 425 105 380 9/28/2023 2750 425 105 427 9/27/2023 2750 400 105 275 9/26/2023 2750 430 106 300 9/25/2023 2750 430 106 272 9/24/2023 2750 430 107 355 9/23/2023 2750 430 106 353 9/22/2023 2750 430 106 356 9/21/2023 2700 430 105 364 9/20/2023 2750 430 107 325 9/19/2023 2750 430 107 310 9/18/2023 2750 430 105 516 9/17/2023 2800 430 105 244 9/16/2023 2700 410 109 250 9/15/2023 2700 415 108 390 9/14/2023 2700 430 108 400 9/13/2023 2700 450 106 451 9/12/2023 2700 440 106 303 9/11/2023 2700 425 106 362 9/10/2023 2700 435 106 418 9/9/2023 2700 430 106 441 9/8/2023 2700 450 106 413 9/7/2023 2650 445 106 232 9/6/2023 2750 450 108 469 9/5/2023 2725 450 107 343 9/4/2023 2750 440 105 385 9/3/2023 2750 440 107 417 9/2/2023 2725 440 108 378 9/1/2023 2725 445 107 372 8/31/2023 2875 440 107 370 8/30/2023 2700 405 105 467 8/29/2023 2700 450 105 343 8/28/2023 2700 460 105 492 8/27/2023 2700 450 105 329 8/26/2023 2700 450 105 324 8/25/2023 2700 450 105 507 8/24/2023 2700 450 106 315 8/23/2023 2725 445 109 370 8/22/2023 2700 445 106 500 8/21/2023 2550 465 106 368 8/20/2023 2625 460 106 257 8/19/2023 2675 435 105 385 8/18/2023 2600 450 106 235 8/17/2023 2700 420 105 345 8/16/2023 2550 470 105 566 8/15/2023 2500 480 105 303 8/14/2023 2200 440 106 94 8/13/2023 2500 465 106 409 8/12/2023 2500 465 106 343 8/11/2023 2500 465 106 358 8/10/2023 2500 475 106 375 8/9/2023 2675 480 107 323 8/8/2023 2675 495 107 397 8/7/2023 2500 470 105 65 8/6/2023 2625 457 107 307 8/5/2023 2650 495 106 366 8/4/2023 2600 475 109 235 8/3/2023 2700 480 105 392 8/2/2023 2500 500 105 427 8/1/2023 2500 470 105 64 7/31/2023 2400 470 105 309 7/30/2023 2500 460 107 298 7/29/2023 2500 470 107 406 7/28/2023 2500 470 107 282 7/27/2023 2500 470 105 390 7/26/2023 2500 470 105 221 7/25/2023 2500 460 105 309 7/24/2023 2500 465 105 372 7/23/2023 2500 465 105 391 7/22/2023 2500 450 105 332 7/21/2023 2500 465 105 399 7/20/2023 2500 470 105 336 7/19/2023 2675 470 105 354 7/18/2023 2575 455 105 244 7/17/2023 2625 445 105 278 7/16/2023 2675 460 105 390 7/15/2023 2650 460 105 383 7/14/2023 2650 440 105 332 7/13/2023 2575 450 105 422 7/12/2023 2600 450 105 243 7/11/2023 2675 445 105 355 7/10/2023 2700 440 105 420 7/9/2023 2500 470 105 188 7/8/2023 2650 450 105 386 7/7/2023 2600 435 105 251 7/6/2023 2600 440 105 275 7/5/2023 2500 450 105 434 7/4/2023 2500 475 105 371 7/3/2023 2400 460 105 161 7/2/2023 2500 450 105 251 7/1/2023 2500 455 105 379 6/30/2023 2500 450 105 292 6/29/2023 2500 450 105 402 6/28/2023 2600 460 105 351 6/27/2023 2650 470 105 313 6/26/2023 2600 470 106 326 6/25/2023 2575 450 105 312 6/24/2023 2600 440 105 282 6/23/2023 2525 470 105 268 6/22/2023 2600 470 105 295 6/21/2023 2500 380 103 267 6/20/2023 2500 380 105 430 6/19/2023 2500 500 103 0 6/18/2023 2500 500 103 318 6/17/2023 2450 450 105 0 6/16/2023 2500 470 105 357 6/15/2023 2450 400 105 204 6/14/2023 2525 470 105 355 6/13/2023 2575 445 105 133 6/12/2023 2600 455 105 335 6/11/2023 2575 480 105 317 6/10/2023 2500 465 105 193 6/9/2023 2600 445 105 312 6/8/2023 2600 460 105 330 6/7/2023 2500 450 105 227 6/6/2023 2600 500 105 309 6/5/2023 2450 450 105 80 6/4/2023 2800 450 105 330 6/3/2023 2700 470 120 282 6/2/2023 3200 430 105 302 6/1/2023 2450 330 104 271 5/31/2023 2525 325 105 261 5/30/2023 2500 435 105 202 5/29/2023 2500 450 105 368 5/28/2023 2500 410 105 189 5/27/2023 2525 405 107 405 5/26/2023 2550 400 105 301 5/25/2023 2525 105 100 400 5/24/2023 2450 104 107 346 5/23/2023 2450 102 110 270 5/22/2023 2450 101 110 195 5/21/2023 2450 101 110 228 5/20/2023 2450 100 110 230 5/19/2023 2450 100 105 192 5/18/2023 2380 100 101 197 5/17/2023 2500 100 100 268 5/16/2023 2575 103 91 325 5/15/2023 2575 105 100 307 5/14/2023 2550 100 110 363 5/13/2023 2575 100 100 344 5/12/2023 2550 100 110 325 5/11/2023 2500 100 100 238 5/10/2023 2450 100 100 312 5/9/2023 2450 100 100 315 5/8/2023 2450 100 100 332 5/7/2023 2450 100 115 339 5/6/2023 2450 100 115 196 5/5/2023 2450 100 120 194 5/4/2023 2450 100 120 220 5/3/2023 2425 100 120 185 5/2/2023 2550 104 130 275 5/1/2023 2500 100 120 302 4/30/2023 2475 100 135 178 4/29/2023 2400 100 140 260 4/28/2023 1800 100 155 65 4/27/2023 2450 100 100 0 4/26/2023 2450 100 100 0 4/25/2023 2450 100 100 233 4/24/2023 2450 100 100 240 4/23/2023 2450 100 100 236 4/22/2023 2450 100 100 251 4/21/2023 2450 100 100 246 4/20/2023 2450 100 100 306 4/19/2023 2450 105 100 277 4/18/2023 2450 100 100 224 4/17/2023 2450 100 100 293 4/16/2023 2500 100 100 252 4/15/2023 2500 100 100 257 4/14/2023 2500 100 100 232 4/13/2023 2500 100 110 256 4/12/2023 2500 100 90 189 4/11/2023 2550 100 80 340 4/10/2023 2500 100 90 233 4/9/2023 2425 101 95 255 4/8/2023 2450 100 90 215 4/7/2023 2500 102 100 328 4/6/2023 2500 101 110 262 4/5/2023 2425 100 90 200 4/4/2023 2550 100 90 273 4/3/2023 2525 100 100 317 4/2/2023 2500 100 105 275 4/1/2023 2525 100 105 282 3/31/2023 2400 100 100 223 3/30/2023 2475 100 95 273 3/29/2023 2500 100 100 235 3/28/2023 2500 100 100 282 3/27/2023 2400 100 100 201 3/26/2023 2500 100 100 254 3/25/2023 2500 100 100 225 3/24/2023 2450 101 95 265 3/23/2023 2350 101 100 284 3/22/2023 2525 95 100 282 3/21/2023 2450 90 100 205 3/20/2023 2450 100 100 200 3/19/2023 2550 105 100 361 3/18/2023 2400 95 100 119 3/17/2023 2500 95 100 295 3/16/2023 2500 105 100 193 3/15/2023 2400 101 90 217 3/14/2023 2400 101 100 300 3/13/2023 2350 100 105 252 3/12/2023 2450 101 105 205 3/11/2023 2350 100 100 263 3/10/2023 2350 101 105 234 3/9/2023 2350 101 120 297 3/8/2023 2475 100 95 150 3/7/2023 2500 100 115 312 3/6/2023 2500 100 145 273 3/5/2023 2000 100 120 0 3/4/2023 2500 100 110 199 3/3/2023 2500 95 101 230 3/2/2023 2425 100 100 295 3/1/2023 2200 105 100 174 2/28/2023 2350 101 110 232 2/27/2023 2350 101 110 241 2/26/2023 2350 100 130 267 2/25/2023 2300 100 120 95 2/24/2023 2350 100 117 298 2/23/2023 2350 100 125 184 2/22/2023 2350 100 85 125 2/21/2023 2400 100 85 290 2/20/2023 2325 101 125 242 2/19/2023 2375 100 155 272 2/18/2023 1975 100 130 0 2/17/2023 2450 100 135 279 2/16/2023 2150 100 125 0 2/15/2023 2300 100 130 306 2/14/2023 2350 100 115 94 2/13/2023 2350 100 115 286 2/12/2023 2400 100 107 233 2/11/2023 2350 101 120 218 2/10/2023 2300 101 110 172 2/9/2023 2350 101 115 238 2/8/2023 2350 101 265 347 2/7/2023 1900 101 250 0 2/6/2023 2300 101 125 207 2/5/2023 0 2/4/2023 2300 101 120 210 2/3/2023 2300 101 120 217 2/2/2023 2300 101 130 226 2/1/2023 2100 100 140 137 1/31/2023 2425 100 110 215 1/30/2023 2400 100 105 248 1/29/2023 2450 100 100 312 1/28/2023 2450 100 120 254 1/27/2023 2400 101 120 208 1/26/2023 2425 100 115 243 1/25/2023 2450 100 140 260 1/24/2023 2350 100 115 128 1/23/2023 2375 103 100 230 1/22/2023 2450 102 120 323 1/21/2023 2400 101 110 170 1/20/2023 2400 101 110 240 1/19/2023 2425 102 115 261 1/18/2023 2300 101 117 258 1/17/2023 2300 101 125 244 1/16/2023 2300 101 120 170 1/15/2023 2300 101 110 235 1/14/2023 2300 101 115 235 1/13/2023 2300 101 110 235 1/12/2023 2300 101 110 225 1/11/2023 2450 101 120 335 1/10/2023 2400 100 115 180 1/9/2023 2375 101 115 150 1/8/2023 2420 102 115 280 1/7/2023 2375 103 135 155 1/6/2023 2400 104 115 223 1/5/2023 2425 101 115 295 1/4/2023 2300 101 115 298 1/3/2023 2300 101 125 288 1/2/2023 2200 101 135 238 1/1/2023 1900 101 135 163 Date Tubing IA OA Water Injection 12/31/2021 2700 150 100 200 12/30/2021 2700 150 100 280 12/29/2021 2625 150 100 0 12/28/2021 2600 160 100 0 12/27/2021 2600 155 100 0 12/26/2021 2600 150 100 236 12/25/2021 2625 140 100 261 12/24/2021 2650 150 100 285 12/23/2021 2600 155 100 223 12/22/2021 2650 140 100 285 12/21/2021 2600 150 100 269 12/20/2021 2650 150 100 248 12/19/2021 2625 125 100 220 12/18/2021 2650 140 99 320 12/17/2021 2625 150 98 313 12/16/2021 2650 140 100 200 12/15/2021 2700 150 99 252 12/14/2021 2700 150 99 170 12/13/2021 2550 150 100 164 12/12/2021 2550 150 100 117 12/11/2021 2500 150 99 192 12/10/2021 2700 140 99 222 12/9/2021 2700 140 98 332 12/8/2021 2700 140 99 278 12/7/2021 2700 140 98 207 12/6/2021 2700 140 98 290 12/5/2021 2650 150 100 260 12/4/2021 2700 150 100 292 Date Range: 01/01/2021 - 12/31/2021 Well: NNA #1 Desc: Disposal Permit to drill: 2012150 Admin Approval: DIO #28A API: 50-133-20507-00-00 12/3/2021 2650 150 99 211 12/2/2021 2600 150 99 198 12/1/2021 2550 140 100 210 11/30/2021 2600 150 100 217 11/29/2021 2600 150 100 283 11/28/2021 2600 150 100 220 11/27/2021 2600 150 100 250 11/26/2021 2625 160 100 239 11/25/2021 2600 175 100 295 11/24/2021 2650 150 99 271 11/23/2021 2650 150 100 279 11/22/2021 2650 150 100 141 11/21/2021 2650 175 100 271 11/20/2021 2550 200 100 198 11/19/2021 2550 200 100 224 11/18/2021 2200 175 100 147 11/17/2021 2525 200 100 193 11/16/2021 2600 210 100 190 11/15/2021 2525 200 100 153 11/14/2021 2450 200 100 202 11/13/2021 2525 210 100 257 11/12/2021 2500 210 100 238 11/11/2021 2575 210 100 320 11/10/2021 2650 240 100 271 11/9/2021 2600 250 100 217 11/8/2021 2600 250 100 267 11/7/2021 2600 250 100 308 11/6/2021 2200 280 101 375 11/5/2021 2550 260 101 92 11/4/2021 2600 250 100 202 11/3/2021 2550 250 100 225 11/2/2021 2600 260 100 310 11/1/2021 2600 260 100 332 10/31/2021 2575 260 100 304 10/30/2021 2500 250 100 165 10/29/2021 2525 260 100 274 10/28/2021 2550 250 100 267 10/27/2021 2600 250 100 255 10/26/2021 2600 250 100 225 10/25/2021 2600 250 100 286 10/24/2021 2550 250 100 279 10/23/2021 2600 275 100 264 10/22/2021 2550 280 100 258 10/21/2021 2500 280 100 192 10/20/2021 2550 275 100 225 10/19/2021 2500 250 100 180 10/18/2021 2550 300 100 253 10/17/2021 2550 290 100 280 10/16/2021 2500 275 100 200 10/15/2021 2550 260 100 250 10/14/2021 2575 300 101 389 10/13/2021 2600 300 100 186 10/12/2021 2600 300 100 223 10/11/2021 2550 300 100 242 10/10/2021 2600 300 100 305 10/9/2021 2550 300 100 185 10/8/2021 2550 300 100 263 10/7/2021 2500 300 100 217 10/6/2021 2550 310 125 275 10/5/2021 2525 300 125 215 10/4/2021 2500 300 100 243 10/3/2021 2525 300 100 217 10/2/2021 2550 300 100 289 10/1/2021 2550 275 100 235 9/30/2021 2500 300 100 412 9/29/2021 2500 280 100 275 9/28/2021 2550 300 100 227 9/27/2021 2500 300 100 186 9/26/2021 2550 300 100 228 9/25/2021 2550 300 100 310 9/24/2021 2500 300 100 225 9/23/2021 2500 300 101 187 9/22/2021 2525 300 101 235 9/21/2021 2525 300 103 300 9/20/2021 2450 300 101 260 9/19/2021 2550 290 101 364 9/18/2021 2550 290 101 342 9/17/2021 2550 350 104 899 9/16/2021 2550 310 101 547 9/15/2021 2550 310 101 253 9/14/2021 2550 350 102 284 9/13/2021 2550 335 102 221 9/12/2021 2550 340 102 223 9/11/2021 2550 350 101 269 9/10/2021 2600 350 101 234 9/9/2021 2550 350 102 209 9/8/2021 2500 325 102 235 9/7/2021 2525 325 102 320 9/6/2021 2500 325 102 200 9/5/2021 2525 325 102 280 9/4/2021 2525 300 101 256 9/3/2021 2525 335 100 320 9/2/2021 2525 335 100 335 9/1/2021 2550 350 101 315 8/31/2021 2550 350 101 262 8/30/2021 2550 360 101 350 8/29/2021 2500 350 101 50 8/28/2021 2500 350 101 232 8/27/2021 2550 350 101 247 8/26/2021 2550 350 101 262 8/25/2021 2525 325 101 210 8/24/2021 2475 350 102 360 8/23/2021 2500 350 101 215 8/22/2021 2550 350 100 305 8/21/2021 2525 350 100 270 8/20/2021 2500 350 101 255 8/19/2021 2550 325 101 305 8/18/2021 2550 350 101 306 8/17/2021 2550 350 101 252 8/16/2021 2500 350 101 265 8/15/2021 2600 350 101 224 8/14/2021 2550 350 101 290 8/13/2021 2550 350 101 306 8/12/2021 2550 355 101 289 8/11/2021 2550 350 101 212 8/10/2021 2550 350 101 279 8/9/2021 2500 360 102 234 8/8/2021 2500 370 101 272 8/7/2021 2500 375 101 306 8/6/2021 2500 375 101 209 8/5/2021 2500 370 101 183 8/4/2021 2450 360 102 230 8/3/2021 2525 360 100 295 8/2/2021 2500 350 100 255 8/1/2021 2525 360 100 335 7/31/2021 2525 350 101 243 7/30/2021 2500 360 100 287 7/29/2021 2475 360 101 222 7/28/2021 2525 375 100 259 7/27/2021 2525 360 100 199 7/26/2021 2500 375 100 268 7/25/2021 2500 390 100 302 7/24/2021 2500 400 100 305 7/23/2021 2500 370 101 98 7/22/2021 2500 375 102 317 7/21/2021 2500 380 100 257 7/20/2021 2500 400 100 267 7/19/2021 2500 400 100 234 7/18/2021 2550 400 100 308 7/17/2021 2500 375 100 257 7/16/2021 2500 375 100 234 7/15/2021 2550 370 100 257 7/14/2021 2500 375 100 231 7/13/2021 2450 350 100 213 7/12/2021 2500 360 100 327 7/11/2021 2500 310 100 232 7/10/2021 2500 375 100 250 7/9/2021 2500 350 102 210 7/8/2021 2500 450 100 338 7/7/2021 2500 375 100 243 7/6/2021 2500 375 100 279 7/5/2021 2500 375 100 229 7/4/2021 2550 375 100 255 7/3/2021 2500 375 100 244 7/2/2021 2550 400 100 314 7/1/2021 2550 400 99 189 6/30/2021 2500 390 100 255 6/29/2021 2500 375 100 250 6/28/2021 2500 375 100 272 6/27/2021 2500 375 100 272 6/26/2021 2500 375 100 310 6/25/2021 2500 375 100 287 6/24/2021 2500 380 100 263 6/23/2021 2550 400 99 245 6/22/2021 2550 400 99 285 6/21/2021 2550 400 100 198 6/20/2021 2500 400 100 221 6/19/2021 2550 400 100 254 6/18/2021 2500 400 100 262 6/17/2021 2500 400 100 327 6/16/2021 2300 400 100 253 6/15/2021 2500 400 99 212 6/14/2021 2500 400 98 293 6/13/2021 2500 400 98 172 6/12/2021 2525 400 99 335 6/11/2021 2500 400 98 250 6/10/2021 2500 400 98 225 6/9/2021 2500 400 99 256 6/8/2021 2500 400 99 310 6/7/2021 2500 400 99 290 6/6/2021 2600 400 99 291 6/5/2021 2500 400 99 298 6/4/2021 2500 400 98 276 6/3/2021 2500 400 99 297 6/2/2021 2550 400 98 315 6/1/2021 2550 400 98 350 5/31/2021 2500 400 96 312 5/30/2021 2500 425 96 298 5/29/2021 2500 425 98 165 5/28/2021 2450 425 96 190 5/27/2021 2500 400 96 274 5/26/2021 2550 440 96 258 5/25/2021 2500 425 96 132 5/24/2021 2500 425 96 229 5/23/2021 2500 400 96 155 5/22/2021 2500 450 96 211 5/21/2021 2500 450 96 60 5/20/2021 2500 425 95 123 5/19/2021 2500 425 95 178 5/18/2021 2500 425 90 177 5/17/2021 2450 425 90 150 5/16/2021 2525 425 90 245 5/15/2021 2500 425 90 195 5/14/2021 2500 425 90 280 5/13/2021 2500 425 90 175 5/12/2021 2500 250 95 194 5/11/2021 2500 325 95 154 5/10/2021 2500 265 95 221 5/9/2021 2500 280 95 177 5/8/2021 2550 270 95 250 5/7/2021 2500 270 95 137 5/6/2021 2600 260 95 156 5/5/2021 2500 250 95 153 5/4/2021 2500 250 95 223 5/3/2021 2500 210 93 150 5/2/2021 2550 210 93 239 5/1/2021 2500 208 95 151 4/30/2021 2500 222 95 242 4/29/2021 2500 212 95 135 4/28/2021 2550 220 94 150 4/27/2021 2500 225 95 138 4/26/2021 2500 230 95 250 4/25/2021 2450 220 94 120 4/24/2021 2525 205 94 190 4/23/2021 2525 200 94 275 4/22/2021 2500 215 94 243 4/21/2021 2500 205 95 190 4/20/2021 2600 215 95 209 4/19/2021 2500 215 95 183 4/18/2021 2500 215 95 160 4/17/2021 2525 210 95 153 4/16/2021 2525 210 95 157 4/15/2021 2525 215 95 203 4/14/2021 2500 200 95 155 4/13/2021 2500 190 95 150 4/12/2021 2600 190 95 200 4/11/2021 2550 180 95 175 4/10/2021 2600 185 95 250 4/9/2021 2600 180 95 145 4/8/2021 2550 195 95 292 4/7/2021 2550 195 96 152 4/6/2021 2550 195 96 173 4/5/2021 2600 180 97 223 4/4/2021 2550 180 97 347 4/3/2021 2550 180 97 331 4/2/2021 2550 185 97 234 4/1/2021 2600 185 97 240 3/31/2021 2550 185 97 325 3/30/2021 2550 190 96 320 3/29/2021 2500 190 98 255 3/28/2021 2600 190 98 240 3/27/2021 2500 195 98 250 3/26/2021 2500 175 98 225 3/25/2021 2550 180 96 412 3/24/2021 2550 180 97 350 3/23/2021 2500 170 97 210 3/22/2021 2575 170 97 325 3/21/2021 2550 160 98 275 3/20/2021 2550 160 99 280 3/19/2021 2550 175 98 265 3/18/2021 2550 165 98 313 3/17/2021 2550 170 99 357 3/16/2021 2550 175 99 296 3/15/2021 2500 170 99 274 3/14/2021 2500 190 99 250 3/13/2021 2500 175 100 165 3/12/2021 2600 180 100 310 3/11/2021 2600 190 100 337 3/10/2021 2575 170 100 255 3/9/2021 2575 180 100 384 3/8/2021 2550 180 100 291 3/7/2021 2550 185 100 275 3/6/2021 2575 175 100 275 3/5/2021 2650 165 100 365 3/4/2021 2575 170 101 392 3/3/2021 2500 180 100 288 3/2/2021 2500 175 100 260 3/1/2021 2550 180 101 295 2/28/2021 2600 175 100 335 2/27/2021 2550 180 100 395 2/26/2021 2600 175 100 352 2/25/2021 2550 170 100 288 2/24/2021 2575 165 100 290 2/23/2021 2550 175 101 308 2/22/2021 2575 180 101 339 2/21/2021 2550 175 101 247 2/20/2021 2500 185 104 285 2/19/2021 2525 185 104 353 2/18/2021 2550 175 102 277 2/17/2021 3000 175 101 280 2/16/2021 3000 172 102 365 2/15/2021 2650 170 102 315 2/14/2021 2800 175 103 375 2/13/2021 2500 175 104 354 2/12/2021 2500 170 102 341 2/11/2021 1550 140 101 270 2/10/2021 2650 170 103 300 2/9/2021 2725 180 103 280 2/8/2021 2700 180 104 208 2/7/2021 2725 175 104 331 2/6/2021 2725 165 103 284 2/5/2021 2750 165 104 290 2/4/2021 2725 175 103 363 2/3/2021 3300 145 103 317 2/2/2021 2800 180 105 360 2/1/2021 2900 160 105 240 1/31/2021 2800 160 105 280 1/30/2021 2700 150 105 340 1/29/2021 2750 150 105 322 1/28/2021 2800 150 105 305 1/27/2021 2750 165 106 435 1/26/2021 2700 195 106 435 1/25/2021 2700 200 107 245 1/24/2021 2725 180 108 210 1/23/2021 2875 165 108 415 1/22/2021 2750 125 109 450 1/21/2021 2675 175 108 200 1/20/2021 2500 170 108 300 1/19/2021 2500 165 109 350 1/18/2021 2525 175 108 435 1/17/2021 2550 175 107 335 1/16/2021 2550 160 108 310 1/15/2021 2550 160 108 355 1/14/2021 2550 160 108 335 1/13/2021 2750 175 107 380 1/12/2021 2700 160 108 385 1/11/2021 2750 165 108 340 1/10/2021 2700 160 109 345 1/9/2021 2650 155 107 409.44 1/8/2021 2725 165 107 373.53 1/7/2021 2750 135 107 342 1/6/2021 2600 140 108 365 1/5/2021 2600 140 108 360 1/4/2021 2600 115 108 270 1/3/2021 2600 130 109 395 1/2/2021 2550 130 109 350 1/1/2021 2600 120 110 450 Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8580 March 24, 2021 Mr. Chris Wallace Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: DEEP CREEK UNIT, HAPPY VALLEY FIELD 2020 ANNUAL Disposal Report for NNA#1 Dear Mr. Wallace: Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2020 as governed by AOGCC Disposal Injection Order #28A, rule #5. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2020 injection history for the NNA #1 well bore. Specific items for this reporting period: ·The fluids injected into the NNA #1 were composed of produced water, pad dewatering, and authorized fluids from neighboring Hilcorp operated leases. ·On May 11, 2019 a successful MIT was witnessed by AOGCC representative Mr. Brian Bixby on the NNA #1. ·The next MIT for the NNA #1 is scheduled for May 2021. ·The average injection pressure in 2020 was approximately 2,560 psig. ·The maximum injection pressure in 2020 was 3,150 psig which is below the permitted 4,000 psig maximum injection pressure. ·Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 4,000 BPD at 2.5 BPM of a slurry laden fluid. In contrast, the well injection volumes during 2020 were no more than 735 BPD at no more than 1.0 BPM instantaneous injection rates. ·The injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore, and operating conditions. Sincerely, Anthony McConkey Reservoir Engineer Digitally signed by Anthony McConkey (2061) DN: cn=Anthony McConkey (2061), ou=Users Date: 2021.03.24 17:54:55 -08'00' Anthony McConkey (2061) Page 2 Attachment 1 – NNA#1 Injection rates and pressures 2020 0 100 200 300 400 500 600 700 800 0 500 1000 1500 2000 2500 1/1/2020 1/31/2020 3/1/2020 4/1/2020 5/1/2020 6/1/2020 7/1/2020 7/31/2020 8/31/2020 9/30/2020 10/31/202011/30/202012/30/2020 In j e c t i o n R a t e ( B W P D ) Pr e s s u r e ( p s i g ) DCU NNA 001 WDW Tubing IA OA Water Injection Date Tubing IA OA Water Injection 12/31/2020 2600 110 110 510 12/30/2020 2700 150 109 360 12/29/2020 2425 110 75 180 12/28/2020 2800 125 110 465 12/27/2020 2800 130 109 450 12/26/2020 2800 135 110 525 12/25/2020 2800 112 85 545 12/24/2020 2800 113 70 525 12/23/2020 2900 130 110 590 12/22/2020 2900 115 110 540 12/21/2020 2600 180 110 540 12/20/2020 2600 160 110 300 12/19/2020 2800 155 110 365 12/18/2020 2550 150 110 360 12/17/2020 2550 16 111 335 12/16/2020 2700 175 110 414 12/15/2020 2750 165 111 414 12/14/2020 2750 160 111 372 12/13/2020 2750 165 111 440 12/12/2020 2725 170 112 455 12/11/2020 2750 170 111 410 12/10/2020 2750 170 111 345 12/9/2020 2500 155 111 420 12/8/2020 2600 155 111 450 12/7/2020 2500 140 111 355 12/6/2020 2500 150 113 425 12/5/2020 2500 175 114 450 12/4/2020 2450 160 113 260 Date Range: 01/01/2020 - 12/31/2020 Well: NNA #1 Desc: Disposal Permit to drill: 2012150 Admin Approval: DIO #28A API: 50-133-20507-00-00 12/3/2020 2400 160 112 360 12/2/2020 2500 170 115 470 12/1/2020 2500 170 115 507 11/30/2020 2500 165 115 450 11/29/2020 3150 160 115 402 11/28/2020 2700 0 115 442 11/27/2020 2700 0 115 467 11/26/2020 2700 200 113 266 11/25/2020 2450 175 114 202 11/24/2020 2700 175 114 735 11/23/2020 2700 165 114 355 11/22/2020 2675 160 115 515 11/21/2020 2675 185 115 474 11/20/2020 2700 165 115 321 11/19/2020 2650 185 115 458 11/18/2020 2675 170 116 334.5 11/17/2020 2650 160 117 620.5 11/16/2020 2600 165 117 336.7 11/15/2020 2600 185 117 350 11/14/2020 2650 180 118 450 11/13/2020 2650 170 117 405 11/12/2020 2650 170 117 316 11/11/2020 2700 190 117 552 11/10/2020 2700 165 117 287 11/9/2020 2700 200 117 510 11/8/2020 2700 180 118 327 11/7/2020 2700 190 115 386 11/6/2020 2700 105 115 279 11/5/2020 2700 90 115 390 11/4/2020 2600 190 116 273 11/3/2020 2650 195 118 475 11/2/2020 2600 170 118 335 11/1/2020 2500 200 118 153 10/31/2020 2575 185 119 474 10/30/2020 2650 195 119 295 10/29/2020 2700 195 120 330 10/28/2020 2700 200 120 394 10/27/2020 2700 200 120 280 10/26/2020 2650 200 120 414 10/25/2020 2650 205 120 342 10/24/2020 2650 205 120 359 10/23/2020 2650 200 120 304 10/22/2020 2550 117 105 278 10/21/2020 2650 205 120 331 10/20/2020 2660 190 120 382 10/19/2020 2625 190 120 460 10/18/2020 2625 180 120 402 10/17/2020 2625 190 120 470 10/16/2020 2650 190 121 418 10/15/2020 2650 185 122 585 10/14/2020 2650 210 122 430 10/13/2020 2650 200 121 380 10/12/2020 2650 225 121 345 10/11/2020 2650 210 125 325 10/10/2020 2650 210 125 435 10/9/2020 2650 210 123 285 10/8/2020 2650 210 123 425 10/7/2020 2650 205 122 221 10/6/2020 2650 200 123 461 10/5/2020 2650 190 125 451 10/4/2020 2650 200 125 530 10/3/2020 2650 200 125 473 10/2/2020 2650 210 125 573 10/1/2020 2650 200 128 547 9/30/2020 2650 200 126 450 9/29/2020 2650 200 126 480 9/28/2020 2650 220 125 335 9/27/2020 2650 220 125 505 9/26/2020 2650 215 125 385 9/25/2020 2650 220 125 380 9/24/2020 2625 225 127 235 9/23/2020 2600 215 126 350 9/22/2020 2650 200 127 453 9/21/2020 2625 215 127 367 9/20/2020 2600 210 125 412 9/19/2020 2625 220 127 415 9/18/2020 2650 225 129 430 9/17/2020 2650 225 127 350 9/16/2020 2650 235 120 485 9/15/2020 2650 220 120 415 9/14/2020 2650 245 125 275 9/13/2020 2650 225 125 320 9/12/2020 2600 225 125 400 9/11/2020 2650 245 125 225 9/10/2020 2650 225 140 380 9/9/2020 2700 270 130 400 9/8/2020 2650 50 128 475 9/7/2020 2650 210 126 493 9/6/2020 2600 215 130 607 9/5/2020 2650 230 130 313 9/4/2020 2625 270 130 412 9/3/2020 2600 270 130 605 9/2/2020 2600 260 130 240 9/1/2020 2600 230 130 480 8/31/2020 2600 245 130 330 8/30/2020 2450 270 130 180 8/29/2020 2600 250 130 440 8/28/2020 2600 290 130 225 8/27/2020 2250 280 131 0 8/26/2020 2600 255 134 255 8/25/2020 2650 250 134 296 8/24/2020 2600 250 134 419 8/23/2020 2600 260 135 351 8/22/2020 2600 265 134 309 8/21/2020 2625 260 134 395 8/20/2020 2600 240 132 430 8/19/2020 2600 255 130 240 8/18/2020 2600 280 130 315 8/17/2020 2600 260 135 245 8/16/2020 2625 260 136 294 8/15/2020 2625 245 136 436 8/14/2020 2625 240 135 380 8/13/2020 2650 240 131 365 8/12/2020 2650 225 136 525 8/11/2020 2600 245 136 315 8/10/2020 2600 225 136 420 8/9/2020 2650 245 135 260 8/8/2020 2650 240 134 425 8/7/2020 2625 255 139 398 8/6/2020 2600 245 136 396 8/5/2020 2600 235 135 435 8/4/2020 2600 255 135 315 8/3/2020 2600 250 135 415 8/2/2020 2600 235 135 435 8/1/2020 2600 250 135 375 7/31/2020 2600 230 135 455 7/30/2020 2600 250 135 420 7/29/2020 2600 280 135 250 7/28/2020 2600 250 140 405 7/27/2020 2600 245 140 340 7/26/2020 2600 260 140 420 7/25/2020 2600 260 140 310 7/24/2020 2500 265 140 190 7/23/2020 2550 260 140 320 7/22/2020 2345 260 140 368 7/21/2020 2575 260 140 358 7/20/2020 2575 250 140 412 7/19/2020 2550 210 140 317 7/18/2020 2550 260 141 332 7/17/2020 2575 260 142 478 7/16/2020 2550 260 140 385 7/15/2020 2600 250 143 196 7/14/2020 2600 250 143 414 7/13/2020 2575 255 143 362 7/12/2020 2600 250 143 412 7/11/2020 2600 250 144 407 7/10/2020 2600 260 145 441 7/9/2020 2600 250 140 345 7/8/2020 2600 230 164 355 7/7/2020 2600 240 146 375 7/6/2020 2600 235 146 405 7/5/2020 2600 250 146 300 7/4/2020 2600 255 146 385 7/3/2020 2600 240 146 380 7/2/2020 2600 255 145 290 7/1/2020 2600 245 145 442 6/30/2020 2600 240 145 446 6/29/2020 2600 220 145 372 6/28/2020 2600 250 145 394 6/27/2020 2550 245 145 316 6/26/2020 2600 230 145 533 6/25/2020 2600 242 142 387 6/24/2020 2600 225 146 290 6/23/2020 2600 220 146 410 6/22/2020 2600 235 146 300 6/21/2020 2600 230 145 435 6/20/2020 2600 230 145 330 6/19/2020 2600 230 145 370 6/18/2020 2600 230 145 310 6/17/2020 2525 260 149 340 6/16/2020 2500 260 149 360 6/15/2020 2550 255 148 335 6/14/2020 2500 255 147 265 6/13/2020 2550 245 147 440 6/12/2020 2525 245 148 445 6/11/2020 2450 250 147 474 6/10/2020 2550 225 147 310 6/9/2020 2550 230 147 315 6/8/2020 2550 225 147 330 6/7/2020 2550 225 147 230 6/6/2020 2550 240 141 265 6/5/2020 2550 233 147 321 6/4/2020 2550 230 147 345 6/3/2020 2525 250 147 333 6/2/2020 2250 230 149 230 6/1/2020 2525 255 149 363 5/31/2020 2500 260 149 288 5/30/2020 2500 260 149 287 5/29/2020 2525 250 149 328 5/28/2020 2575 245 149 375 5/27/2020 2550 265 149 280 5/26/2020 2450 285 149 82 5/25/2020 2550 235 149 80 5/24/2020 2550 215 149 260 5/23/2020 2550 235 149 150 5/22/2020 2500 255 149 285 5/21/2020 2500 250 149 125 5/20/2020 2500 255 149 286 5/19/2020 2500 265 148 224 5/18/2020 2450 250 150 280 5/17/2020 2500 265 146 351 5/16/2020 2245 270 146 124 5/15/2020 2550 260 150 304 5/14/2020 2500 260 148 296 5/13/2020 2550 240 148 215 5/12/2020 2550 230 148 315 5/11/2020 2550 230 148 110 5/10/2020 2550 200 148 310 5/9/2020 2550 230 148 280 5/8/2020 2550 215 148 55 5/7/2020 2550 220 148 306 5/6/2020 2500 250 147 250 5/5/2020 2425 242 146 204 5/4/2020 2525 235 148 350 5/3/2020 2500 250 148 206 5/2/2020 2500 240 148 312 5/1/2020 2450 240 146 185 4/30/2020 2550 235 146 275 4/29/2020 2550 215 147 298 4/28/2020 2550 220 147 401 4/27/2020 2500 225 147 90 4/26/2020 2550 210 147 183 4/25/2020 2550 220 147 382 4/24/2020 2500 220 146 205 4/23/2020 2150 215 145 130 4/22/2020 2340 225 145 455 4/21/2020 2255 220 145 235 4/20/2020 2500 215 145 317 4/19/2020 2550 190 145 443 4/18/2020 2550 105 146 452 4/17/2020 2525 235 145 422 4/16/2020 2500 230 145 281 4/15/2020 2550 220 148 328 4/14/2020 2550 210 148 330 4/13/2020 2550 215 148 238 4/12/2020 2550 220 148 495 4/11/2020 2550 210 148 428 4/10/2020 2500 210 148 363 4/9/2020 2500 220 148 230 4/8/2020 2525 215 149 405 4/7/2020 2400 220 147 265 4/6/2020 2525 220 150 507 4/5/2020 2525 215 150 460 4/4/2020 2525 210 148 326 4/3/2020 2500 205 150 464 4/2/2020 2550 220 148 415 4/1/2020 2500 215 148 310 3/31/2020 2500 220 148 330 3/30/2020 2500 220 148 365 3/29/2020 2500 210 148 370 3/28/2020 2500 220 148 375 3/27/2020 2500 225 150 277 3/26/2020 2450 220 145 443 3/25/2020 2500 220 146 270 3/24/2020 2500 220 146 340 3/23/2020 2500 230 146 320 3/22/2020 2500 220 146 245 3/21/2020 2500 220 146 405 3/20/2020 2500 224 146 240 3/19/2020 2400 220 146 160 3/18/2020 2550 220 147 363 3/17/2020 2525 260 145 367 3/16/2020 2400 220 145 300 3/15/2020 2500 205 145 410 3/14/2020 2500 205 145 425 3/13/2020 2500 230 148 265 3/12/2020 2500 205 145 294 3/11/2020 2450 225 145 360 3/10/2020 2450 215 144 346 3/9/2020 2500 215 144 295 3/8/2020 2450 215 144 335 3/7/2020 2500 205 144 265 3/6/2020 2450 210 144 420 3/5/2020 2450 210 146 372 3/4/2020 2500 205 143 329 3/3/2020 2500 205 143 363 3/2/2020 2500 210 143 420 3/1/2020 2500 215 140 338 2/29/2020 2500 215 140 319.9 2/28/2020 2550 215 140 245 2/27/2020 2500 210 140 293 2/26/2020 2450 210 141 390 2/25/2020 2475 220 142 277 2/24/2020 2475 215 142 298 2/23/2020 2500 200 142 535 2/22/2020 2475 205 140 333 2/21/2020 2450 220 140 357 2/20/2020 2400 210 139 427 2/19/2020 2500 210 140 425 2/18/2020 2500 210 140 373 2/17/2020 2500 210 140 220 2/16/2020 2500 210 138 416 2/15/2020 2500 210 138 343 2/14/2020 2500 220 137 239 2/13/2020 2350 137 30 272 2/12/2020 2450 215 138 387 2/11/2020 2475 215 138 297 2/10/2020 2450 205 139 461 2/9/2020 2450 215 138 360 2/8/2020 2450 210 135 380 2/7/2020 2500 210 135 282 2/6/2020 2500 205 135 373 2/5/2020 2500 210 133 355 2/4/2020 2500 200 133 200 2/3/2020 2500 200 133 445 2/2/2020 2500 180 133 462 2/1/2020 2500 210 132 243 1/31/2020 2500 210 130 340 1/30/2020 2500 220 130 210 1/29/2020 2365 175 130 320 1/28/2020 2415 175 130 325 1/27/2020 2450 180 130 500 1/26/2020 2285 200 130 225 1/25/2020 2405 215 130 225 1/24/2020 2435 190 130 390 1/23/2020 2500 200 135 352 1/22/2020 2500 210 135 310 1/21/2020 2500 190 135 396.7 1/20/2020 2500 200 135 386.8 1/19/2020 2500 220 135 243.2 1/18/2020 2500 190 253.3 1/17/2020 2500 190 125 410 1/16/2020 2500 200 125 381 1/15/2020 2410 205 123 247 1/14/2020 2390 195 124 335 1/13/2020 2485 190 123 390 1/12/2020 2400 185 121 420 1/11/2020 2450 185 121 441 1/10/2020 2450 170 120 385 1/9/2020 2500 190 120 365 1/8/2020 2450 210 125 337 1/7/2020 2500 200 125 220 1/6/2020 2300 170 125 380 1/5/2020 2400 220 120 89 1/4/2020 2450 190 120 360 1/3/2020 2450 170 117 257 1/2/2020 2500 170 117 338 1/1/2020 2430 160 117 425 Date Tubing IA OA Water Injection 4/28/2020 0 4/27/2020 2500 225 147 90 4/26/2020 2550 210 147 183 4/25/2020 2550 220 147 382 4/24/2020 2500 220 146 205 4/23/2020 2150 215 145 130 4/22/2020 2340 225 145 455 4/21/2020 2255 220 145 235 4/20/2020 2500 215 145 317 4/19/2020 2550 190 145 443 4/18/2020 2550 105 146 452 4/17/2020 2525 235 145 422 4/16/2020 2500 230 145 281 4/15/2020 2550 220 148 328 4/14/2020 2550 210 148 330 4/13/2020 2550 215 148 238 4/12/2020 2550 220 148 495 4/11/2020 2550 210 148 428 4/10/2020 2500 210 148 363 4/9/2020 2500 220 148 230 4/8/2020 2525 215 149 405 4/7/2020 2400 220 147 265 4/6/2020 2525 220 150 507 4/5/2020 2525 215 150 460 4/4/2020 2525 210 148 326 4/3/2020 2500 205 150 464 4/2/2020 2550 220 148 415 4/1/2020 2500 215 148 310 Date Range: 01/01/2019 - 04/28/2020 Well: NNA #1 Desc: Disposal Permit to drill: 2012150 Admin Approval: DIO #28A API: 50-133-20507-00-00 3/31/2020 2500 220 148 330 3/30/2020 2500 220 148 365 3/29/2020 2500 210 148 370 3/28/2020 2500 220 148 375 3/27/2020 2500 225 150 277 3/26/2020 2450 220 145 443 3/25/2020 2500 220 146 270 3/24/2020 2500 220 146 340 3/23/2020 2500 230 146 320 3/22/2020 2500 220 146 245 3/21/2020 2500 220 146 405 3/20/2020 2500 224 146 240 3/19/2020 2400 220 146 160 3/18/2020 2550 220 147 363 3/17/2020 2525 260 145 367 3/16/2020 2400 220 145 300 3/15/2020 2500 205 145 410 3/14/2020 2500 205 145 425 3/13/2020 2500 230 148 265 3/12/2020 2500 205 145 294 3/11/2020 2450 225 145 360 3/10/2020 2450 215 144 346 3/9/2020 2500 215 144 295 3/8/2020 2450 215 144 335 3/7/2020 2500 205 144 265 3/6/2020 2450 210 144 420 3/5/2020 2450 210 146 372 3/4/2020 2500 205 143 329 3/3/2020 2500 205 143 363 3/2/2020 2500 210 143 420 3/1/2020 2500 215 140 338 2/29/2020 2500 215 140 319.9 2/28/2020 2550 215 140 245 2/27/2020 2500 210 140 293 2/26/2020 2450 210 141 390 2/25/2020 2475 220 142 277 2/24/2020 2475 215 142 298 2/23/2020 2500 200 142 535 2/22/2020 2475 205 140 333 2/21/2020 2450 220 140 357 2/20/2020 2400 210 139 427 2/19/2020 2500 210 140 425 2/18/2020 2500 210 140 373 2/17/2020 2500 210 140 220 2/16/2020 2500 210 138 416 2/15/2020 2500 210 138 343 2/14/2020 2500 220 137 239 2/13/2020 2350 137 30 272 2/12/2020 2450 215 138 387 2/11/2020 2475 215 138 297 2/10/2020 2450 205 139 461 2/9/2020 2450 215 138 360 2/8/2020 2450 210 135 380 2/7/2020 2500 210 135 282 2/6/2020 2500 205 135 373 2/5/2020 2500 210 133 355 2/4/2020 2500 200 133 200 2/3/2020 2500 200 133 445 2/2/2020 2500 180 133 462 2/1/2020 2500 210 132 243 1/31/2020 2500 210 130 340 1/30/2020 2500 220 130 210 1/29/2020 2365 175 130 320 1/28/2020 2415 175 130 325 1/27/2020 2450 180 130 500 1/26/2020 2285 200 130 225 1/25/2020 2405 215 130 225 1/24/2020 2435 190 130 390 1/23/2020 2500 200 135 352 1/22/2020 2500 210 135 310 1/21/2020 2500 190 135 396.7 1/20/2020 2500 200 135 386.8 1/19/2020 2500 220 135 243.2 1/18/2020 2500 190 253.3 1/17/2020 2500 190 125 410 1/16/2020 2500 200 125 381 1/15/2020 2410 205 123 247 1/14/2020 2390 195 124 335 1/13/2020 2485 190 123 390 1/12/2020 2400 185 121 420 1/11/2020 2450 185 121 441 1/10/2020 2450 170 120 385 1/9/2020 2500 190 120 365 1/8/2020 2450 210 125 337 1/7/2020 2500 200 125 220 1/6/2020 2300 170 125 380 1/5/2020 2400 220 120 89 1/4/2020 2450 190 120 360 1/3/2020 2450 170 117 257 1/2/2020 2500 170 117 338 1/1/2020 2430 160 117 425 12/31/2019 2460 145 115 545 12/30/2019 2450 105 122 585 12/29/2019 2450 120 121 675 12/28/2019 2425 130 121 555 12/27/2019 2525 150 122 410 12/26/2019 2525 150 120 960 12/25/2019 2500 170 105 543.4 12/24/2019 2500 170 105 410.1 12/23/2019 2500 150 105 285.5 12/22/2019 2500 150 105 566.8 12/21/2019 2500 140 105 488.2 12/20/2019 2550 110 110 802 12/19/2019 2500 150 105 608 12/18/2019 2500 150 102 642 12/17/2019 2500 150 101 659 12/16/2019 2500 130 100 784 12/15/2019 2475 150 100 670 12/14/2019 2475 155 98 650 12/13/2019 2475 150 97 645 12/12/2019 2500 160 95 630 12/11/2019 2500 200 95 815 12/10/2019 2500 200 95 445 12/9/2019 2500 200 95 445 12/8/2019 2500 200 90 330 12/7/2019 2500 180 90 433 12/6/2019 2500 150 90 540 12/5/2019 2400 190 90 411 12/4/2019 2400 155 90 467 12/3/2019 2400 165 90 615 12/2/2019 2400 130 90 639 12/1/2019 2400 115 90 586 11/30/2019 2350 200 90 450 11/29/2019 2200 210 90 245 11/28/2019 2375 205 90 442 11/27/2019 2600 190 95 440 11/26/2019 2600 190 95 450 11/25/2019 2600 180 93 524 11/24/2019 2600 170 90 668 11/23/2019 2600 210 90 473 11/22/2019 2600 210 90 628 11/21/2019 2600 190 90 371 11/20/2019 2575 215 90 452 11/19/2019 2550 210 90 405 11/18/2019 2600 175 90 535 11/17/2019 2550 135 90 573 11/16/2019 2575 180 90 513 11/15/2019 2550 210 90 718 11/14/2019 2550 205 90 283 11/13/2019 2550 200 93 557 11/12/2019 2525 200 93 518 11/11/2019 2550 190 93 600 11/10/2019 2525 160 94 615 11/9/2019 2500 200 94 523 11/8/2019 2525 205 95 572 11/7/2019 2250 190 95 545 11/6/2019 2550 190 95 530 11/5/2019 2550 210 95 424 11/4/2019 2550 210 95 530 11/3/2019 2550 300 95 693 11/2/2019 2550 220 95 443 11/1/2019 2550 210 95 605 10/31/2019 2500 185 93 627 10/30/2019 2500 265 90 480 10/29/2019 2500 250 90 562 10/28/2019 2500 250 90 274 10/27/2019 2500 220 88 387 10/26/2019 2500 230 85 335 10/25/2019 2500 220 85 465 10/24/2019 2500 215 85 279 10/23/2019 2450 185 86 538 10/22/2019 2500 185 85 532 10/21/2019 2500 180 85 510 10/20/2019 2500 170 84 537 10/19/2019 2500 165 85 533 10/18/2019 2500 175 85 600 10/17/2019 2500 170 83 610 10/16/2019 2500 170 80 538 10/15/2019 2500 160 80 613 10/14/2019 2500 190 78 530 10/13/2019 2500 180 75 607 10/12/2019 2500 170 75 560 10/11/2019 2500 170 75 590 10/10/2019 2500 200 75 531 10/9/2019 2450 195 75 378 10/8/2019 2425 180 73 657 10/7/2019 2450 190 71 573 10/6/2019 2425 195 70 570 10/5/2019 2425 195 70 573 10/4/2019 2500 205 67 507 10/3/2019 2450 210 65 530 10/2/2019 2400 200 65 588 10/1/2019 2400 200 63 502 9/30/2019 2425 190 57 582 9/29/2019 2400 190 57 583 9/28/2019 2400 195 57 499 9/27/2019 2500 160 57 726 9/26/2019 2600 185 65 628 9/25/2019 2550 220 52 515 9/24/2019 2500 210 51 507 9/23/2019 2500 210 50 548 9/22/2019 2550 160 45 582 9/21/2019 2600 220 45 598 9/20/2019 2500 250 45 200 9/19/2019 2600 160 40 695 9/18/2019 2600 250 40 492 9/17/2019 2600 260 40 463 9/16/2019 2600 250 35 560 9/15/2019 2600 270 35 443 9/14/2019 2600 240 33 593.5 9/13/2019 2600 290 30 425 9/12/2019 2600 290 35 403 9/11/2019 2400 290 35 540 9/10/2019 2400 275 29 499 9/9/2019 2500 275 27 626 9/8/2019 2500 285 25 545 9/7/2019 2600 280 25 442 9/6/2019 2600 310 24 610 9/5/2019 2600 310 22 477 9/4/2019 2525 305 20 521 9/3/2019 2550 305 18 545 9/2/2019 2525 305 0 525 9/1/2019 2550 310 0 485 8/31/2019 2525 320 0 482 8/30/2019 2525 300 0 575 8/29/2019 2600 320 0 489 8/28/2019 2600 330 0 562 8/27/2019 2600 330 50 380 8/26/2019 2600 310 50 420 8/25/2019 2600 390 50 430 8/24/2019 2600 350 50 420 8/23/2019 2550 330 47 485 8/22/2019 2600 335 45 555 8/21/2019 1550 310 40 530 8/20/2019 2600 310 40 591 8/19/2019 2600 310 40 685 8/18/2019 2600 320 30 630 8/17/2019 2600 420 30 683 8/16/2019 2600 410 30 480 8/15/2019 2550 400 0 375 8/14/2019 2550 365 0 465 8/13/2019 2550 355 0 691 8/12/2019 2575 370 0 603 8/11/2019 2550 345 0 607 8/10/2019 2550 360 0 621 8/9/2019 2550 360 0 597 8/8/2019 2600 360 0 613 8/7/2019 2600 360 0 600 8/6/2019 2600 360 0 624 8/5/2019 2600 340 0 602 8/4/2019 2600 340 0 603 8/3/2019 2600 350 0 572 8/2/2019 2600 340 0 540 8/1/2019 2600 350 0 515 7/31/2019 2575 355 0 595 7/30/2019 2550 310 0 338 7/29/2019 2600 310 0 934 7/28/2019 2550 360 0 538 7/27/2019 2525 360 0 530 7/26/2019 2550 360 0 576 7/25/2019 2600 370 0 573.5 7/24/2019 2600 380 0 599.9 7/23/2019 2300 380 0 511.1 7/22/2019 2600 390 0 540 7/21/2019 2600 390 0 600 7/20/2019 2600 380 0 603.3 7/19/2019 2600 390 0 465.7 7/18/2019 2600 380 0 456.5 7/17/2019 2525 380 0 635 7/16/2019 2525 380 0 540 7/15/2019 2525 380 0 580 7/14/2019 2525 385 0 560 7/13/2019 2525 395 0 505 7/12/2019 2500 325 0 889 7/11/2019 2600 395 0 656 7/10/2019 2600 430 0 400 7/9/2019 2600 410 0 626 7/8/2019 2600 420 0 663 7/7/2019 2500 420 0 535 7/6/2019 2500 410 0 658 7/5/2019 2500 440 0 530 7/4/2019 2500 460 0 385 7/3/2019 2450 465 0 375 7/2/2019 2450 465 0 367 7/1/2019 2450 460 0 373 6/30/2019 2450 460 0 375 6/29/2019 2450 460 0 374 6/28/2019 2450 460 0 376 6/27/2019 2550 455 0 216 6/26/2019 2600 450 0 396 6/25/2019 2600 440 0 300 6/24/2019 2600 430 0 344 6/23/2019 2600 380 0 779 6/22/2019 2600 390 0 613 6/21/2019 2600 390 0 606.7 6/20/2019 2550 380 0 705 6/19/2019 2500 395 0 685 6/18/2019 2500 330 0 817 6/17/2019 2475 400 0 550 6/16/2019 2500 395 0 733 6/15/2019 2500 385 0 693 6/14/2019 2450 380 0 739 6/13/2019 2550 375 0 728 6/12/2019 2600 380 0 770 6/11/2019 2600 410 0 566.6 6/10/2019 2600 430 0 524.7 6/9/2019 2550 410 0 700 6/8/2019 2550 480 0 353.2 6/7/2019 2450 480 0 390.1 6/6/2019 2400 480 0 115 6/5/2019 2400 450 0 347 6/4/2019 2425 445 0 375 6/3/2019 2400 450 0 375 6/2/2019 2400 435 0 445 6/1/2019 2375 450 0 480 5/31/2019 2400 455 0 453 5/30/2019 2550 460 0 239 5/29/2019 2500 480 0 267.2 5/28/2019 2500 500 0 463.4 5/27/2019 2500 500 0 442.9 5/26/2019 2500 500 0 245.1 5/25/2019 2500 500 0 299.6 5/24/2019 2500 480 0 468 5/23/2019 2350 480 0 215 5/22/2019 2400 480 0 160 5/21/2019 2400 475 0 405 5/20/2019 2400 485 0 260 5/19/2019 2550 480 0 382 5/18/2019 2400 470 0 453 5/17/2019 2400 480 0 445 5/16/2019 2500 480 0 463 5/15/2019 2500 500 0 415 5/14/2019 2500 500 0 213 5/13/2019 2550 500 0 293 5/12/2019 2500 400 0 330 5/11/2019 2550 500 0 265 5/10/2019 2500 490 0 404 5/9/2019 2400 480 0 206 5/8/2019 2380 490 0 410 5/7/2019 2400 490 0 305 5/6/2019 2375 490 0 389 5/5/2019 2400 495 0 308 5/4/2019 2325 520 0 110 5/3/2019 2400 525 0 260 5/2/2019 2600 525 0 265 5/1/2019 2550 500 0 273 4/30/2019 2450 500 0 214 4/29/2019 2550 400 0 168 4/28/2019 2550 400 0 295 4/27/2019 2550 350 0 153 4/26/2019 2500 400 0 247 4/25/2019 2450 300 0 350 4/24/2019 2400 350 0 491 4/23/2019 2400 500 0 301 4/22/2019 2440 505 0 240 4/21/2019 2400 510 0 256 4/20/2019 2340 500 0 162 4/19/2019 2390 500 0 304 4/18/2019 2600 500 0 283 4/17/2019 2600 450 0 330 4/16/2019 2550 450 0 266.5 4/15/2019 2500 450 0 205.5 4/14/2019 2650 450 0 207 4/13/2019 2650 450 0 213 4/12/2019 2450 500 0 180.7 4/11/2019 2425 500 0 45 4/10/2019 2400 490 0 335 4/9/2019 2425 225 0 318 4/8/2019 2400 230 0 358 4/7/2019 2400 220 0 310 4/6/2019 2400 225 0 275 4/5/2019 2400 235 0 359 4/4/2019 2375 240 0 318 4/3/2019 2600 250 0 221 4/2/2019 2600 180 0 376 4/1/2019 2600 200 0 349 3/31/2019 2600 190 0 296 3/30/2019 2600 240 0 193 3/29/2019 2550 240 0 397 3/28/2019 2320 210 0 80 3/27/2019 2435 210 0 247 3/26/2019 2425 210 0 373 3/25/2019 2460 210 0 287 3/24/2019 2300 205 0 130 3/23/2019 2440 195 0 397 3/22/2019 2430 210 0 285 3/21/2019 2600 190 0 527 3/20/2019 2600 190 0 312 3/19/2019 2600 180 0 287 3/18/2019 2600 190 0 255 3/17/2019 2550 190 0 322 3/16/2019 2550 190 0 443 3/15/2019 2500 180 0 365 3/14/2019 2400 150 0 551 3/13/2019 2600 165 0 408 3/12/2019 2500 160 0 493 3/11/2019 2500 170 0 255 3/10/2019 2500 115 0 525 3/9/2019 2600 0 0 995 3/8/2019 2525 125 1050 3/7/2019 2425 160 635 3/6/2019 2600 130 525 3/5/2019 2550 120 530 3/4/2019 2600 110 0 640 3/3/2019 2600 110 0 975.4 3/2/2019 2500 170 0 440 3/1/2019 2500 120 0 703.5 2/28/2019 2515 130 0 564 2/27/2019 2500 30 0 958 2/26/2019 2550 120 0 569 2/25/2019 2525 115 0 542 2/24/2019 2500 120 0 683 2/23/2019 2500 90 0 602 2/22/2019 2525 105 0 655 2/21/2019 2500 200 0 698 2/20/2019 2500 200 0 461 2/19/2019 2500 190 0 469 2/18/2019 2500 200 0 406 2/17/2019 2500 180 0 354.7 2/16/2019 2500 200 0 384.3 2/15/2019 2500 170 0 317 2/14/2019 2500 170 0 357 2/13/2019 2575 160 0 318 2/12/2019 2500 140 0 621 2/11/2019 2500 165 0 479 2/10/2019 2450 135 0 725 2/9/2019 2450 155 0 610 2/8/2019 2450 165 0 520 2/7/2019 2500 85 0 682 2/6/2019 2500 180 0 280 2/5/2019 2400 170 0 203 2/4/2019 2500 100 0 224 2/3/2019 2500 170 0 350 2/2/2019 2300 150 0 293 2/1/2019 2500 170 0 528 1/31/2019 2500 180 0 319 1/30/2019 2500 155 0 584 1/29/2019 2475 180 0 453 1/28/2019 2450 180 0 355 1/27/2019 2475 240 0 511 1/26/2019 2450 170 0 520 1/25/2019 2450 100 0 405 1/24/2019 2500 110 0 465 1/23/2019 2500 200 0 424 1/22/2019 2450 220 0 302 1/21/2019 2500 180 0 222 1/20/2019 2500 200 0 475 1/19/2019 2500 210 0 147 1/18/2019 2450 200 0 250 1/17/2019 2450 190 0 176 1/16/2019 2450 100 0 437 1/15/2019 2500 110 0 375 1/14/2019 2500 170 0 392 1/13/2019 2525 150 0 175 1/12/2019 2525 100 0 615 1/11/2019 2525 65 0 718 1/10/2019 2550 100 0 800 1/9/2019 2330 180 0 383 1/8/2019 2500 90 0 673 1/7/2019 2500 150 0 847 1/6/2019 2500 100 0 868 1/5/2019 2500 160 0 975 1/4/2019 2450 140 0 506 1/3/2019 2525 100 0 893 1/2/2019 2500 100 0 762 1/1/2019 2500 185 0 685 ff Hilcorp Alaska, LLC June 25, 2019 Mr. Chris Wallace Alaska Oil & Gas Conservation Commission 333 W. 7" Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: DEEP CREEK UNIT, HAPPY VALLEY FIELD 2018 ANNUAL Disposal Report for NNA#1 Dear Mr. Wallace: Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8322 Fax: 907/777-8580 JUL 0 1 MD AOGCC Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2018 as governed by AOGCC Disposal Injection Order #28A, rule #5. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2018 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were composed of —98% produced water from Happy Valley wells • On May 11, 2019 a successful MIT was witnessed by AOGCC representative Mr. Brian Bixby on the NNA #1. • The next MIT for the NNA #I is scheduled for May 2021. • The average injection pressure in 2018 was approximately 2,200 psig. • The maximum injection pressure in 2018 was 2,525 prig which is below the permitted 4,000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 4,000 BPD at 2.5 BPM of a slurry laden fluid. In contrast, the well injection volumes during 2018 were no more than 1,157 BPD at no more than 1.0 BPM instantaneous injection rates. • The injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore, and operating conditions. aE key Reservoir Engineer Attachment 1 — NNA# I Injection rates and pressures 2018 2500 2000- 000- 1500- 1500- 1000- 1000- -mm .mm a DCU NNA 001 WDW 01/2018 02/2018 03/2018 04/2018 05/2018 06/2018 07/2018 08/2018 09/2018 10/2018 11/2018 12/2018 — Tubing — IA — OA — Water Injection 1200 1000 m m 400 200 V Well: NNA#1 Desc: Disposal Permit to drill: 2012150 Admin Approval: DIO #28A API: 50-133-20507-00-00 Date Range: 01/01/2018 - 12/31/2018 Date Tubing IA OA Water Injection 12/31/2018 2525 185 0 335 12/30/2018 2500 5 0 1023 12/29/2018 2500 180 0 552 12/28/2018 2450 45 0 1073 12/27/2018 2450 190 0 647 12/26/2018 2450 230 251.8 12/25/2018 2450 210 470.3 12/24/2018 2500 190 518 12/23/2018 2450 110 0 544 12/22/2018 2450 110 0 616.5 12/21/2018 2450 180 0 262 12/20/2018 2450 180 0 431 12/19/2018 2450 180 0 533.5 12/18/2018 2450 160 0 433.3 12/17/2018 2450 170 0 428.3 12/16/2018 2450 175 0 580 12/15/2018 2450 180 0 603.5 12/14/2018 2450 180 0 635 12/13/2018 2450 170 0 491 12/12/2018 2450 145 0 866 12/11/2018 2450 155 0 619 12/10/2018 2450 180 0 1157 12/9/2018 2400 175 0 704 12/8/2018 2400 180 0 483 12/7/2018 2450 190 0 520 12/6/2018 2400 210 0 368 12/5/2018 2400 210 0 442 12/4/2018 2350 215 0 268 12/3/2018 2350 195 0 360 12/2/2018 2375 200 0 348 12/1/2018 2375 205 0 342 11/30/2018 2400 200 0 350 11/29/2018 2450 190 0 502 11/28/2018 2450 200 0 561 11/27/2018 2450 160 0 476 11/26/2018 2450 180 0 399 11/25/2018 2450 120 0 791 11/24/2018 2450 150 0 646 11/23/2018 2475 110 0 800.5 11/22/2018 2450 160 0 477 11/21/2018 2450 155 0 765 11/20/2018 2450 175 0 660 11/19/2018 2400 150 0 605 11/18/2018 2450 160 0 540 11/17/2018 2400 110 0 696 11/16/2018 2375 155 0 390 11/15/2018 2400 160 0 477 11/14/2018 2450 180 0 482 11/13/2018 2450 160 0 384 11/12/2018 2450 150 0 523 11/11/2018 2450 140 0 682 11/10/2018 2450 170 0 564 11/9/2018 2450 150 0 889 11/8/2018 2400 150 0 565 11/7/2018 2400 155 0 570 11/6/2018 2400 150 0 622 11/5/2018 2400 155 0 633 11/4/2018 2375 175 0 632 11/3/2018 2350 190 0 436 11/2/2018 2350 185 0 357 11/1/2018 2400 190 0 574 10/31/2018 2400 180 0 360 10/30/2018 2400 180 477 10/29/2018 2400 180 368 10/28/2018 2400 200 473 10/27/2018 2400 180 355 10/26/2018 2400 140 602 10/25/2018 2350 170 539 10/24/2018 2300 90 512 10/23/2018 2350 180 544 10/22/2018 2300 175 724 10/21/2018 2300 190 451 10/20/2018 2300 175 495 10/19/2018 2350 160 380 10/18/2018 2300 175 685 10/17/2018 2350 160 0 470 10/16/2018 2350 170 0 397 10/15/2018 2350 160 0 602 10/14/2018 2350 170 0 565 10/13/2018 2300 160 0 715 10/12/2018 2300 200 0 409 10/11/2018 2300 200 0 608 10/10/2018 2325 190 0 415 10/9/2018 2350 140 0 910 10/8/2018 2300 180 0 615 10/7/2018 2300 180 0 643 10/6/2018 2300 180 0 632 10/5/2018 2300 190 0 625 10/4/2018 2300 210 0 632 10/3/2018 2300 210 0 230 10/2/2018 2300 210 0 398 10/1/2018 2300 220 0 323 9/30/2018 2300 200 0 448 9/29/2018 2300 200 0 595 9/28/2018 2300 200 0 498 9/27/2018 2300 200 0 516 9/26/2018 2300 205 0 557 9/25/2018 2300 210 0 520 9/24/2018 2300 210 0 480 9/23/2018 2300 200 0 520 9/22/2018 2300 195 0 570 9/21/2018 2300 190 0 590 9/20/2018 2350 200 0 508 9/19/2018 2330 200 0 485 9/18/2018 2300 200 0 572 9/17/2018 2300 200 0 387 9/16/2018 2300 200 0 460 9/15/2018 2300 200 0 833 9/14/2018 2330 200 0 549 9/13/2018 2300 200 0 496 9/12/2018 2300 200 0 570 9/11/2018 2300 205 0 475 9/10/2018 2300 190 0 662 9/9/2018 2300 205 0 448 9/8/2018 2300 205 0 637 9/7/2018 2300 205 0 498 9/6/2018 2350 205 0 455 9/5/2018 2300 200 0 584 9/4/2018 2300 200 0 506 9/3/2018 2300 200 0 551 9/2/2018 2330 190 0 553 9/1/2018 2300 220 0 388 8/31/2018 2300 200 0 191 8/30/2018 2250 200 0 512 8/29/2018 2300 200 0 460 8/28/2018 2275 190 0 535 8/27/2018 2275 200 0 596 8/26/2018 2250 210 0 263 8/25/2018 2250 190 0 645 8/24/2018 2250 210 0 320 8/23/2018 2275 210 0 560 8/22/2018 2300 210 0 500 8/21/2018 2275 200 0 573 8/20/2018 2275 215 0 517 8/19/2018 2275 205 0 520 8/18/2018 2300 180 0 572 8/17/2018 2250 185 0 603 8/16/2018 2275 210 0 500 8/15/2018 2275 200 0 620 8/14/2018 2275 205 0 540 8/13/2018 2275 200 0 590 8/12/2018 2275 130 0 925 8/11/2018 2275 200 0 639 8/10/2018 2225 205 0 721 8/9/2018 2250 210 0 423 8/8/2018 2250 210 0 591 8/7/2018 2250 210 0 572 8/6/2018 2250 220 0 495 8/5/2018 2250 275 0 437 8/4/2018 2250 280 0 571 8/3/2018 2250 280 0 640 8/2/2018 2075 280 0 155 8/1/2018 2125 285 0 300 7/31/2018 2150 275 0 245 7/30/2018 2050 265 0 301 7/29/2018 2125 265 0 237 7/28/2018 2025 265 0 262 7/27/2018 2100 260 0 230 7/26/2018 2200 260 0 392 7/25/2018 2200 260 0 277 7/24/2018 2200 260 0 198 7/23/2018 2250 260 0 237 7/22/2018 2150 260 0 233 7/21/2018 2250 260 0 222 7/20/2018 2200 230 0 230 7/19/2018 2200 220 0 290 7/18/2018 2222 222 0 222 7/17/2018 2250 235 0 325 7/16/2018 2250 220 0 453 7/15/2018 2225 210 0 392 7/14/2018 2250 210 0 540 7/13/2018 2225 210 0 600 7/12/2018 2200 225 0 543 7/11/2018 2200 220 393 7/10/2018 2200 220 665.14 7/9/2018 2200 220 311.8 7/8/2018 2200 230 560 7/7/2018 2250 210 664 7/6/2018 2200 230 0 635.3 7/5/2018 2250 230 0 472 7/4/2018 2250 230 0 465 7/3/2018 2250 200 0 633 7/2/2018 2250 220 0 517 7/1/2018 2250 205 0 590 6/30/2018 2200 190 0 510 6/29/2018 2200 210 0 479 6/28/2018 2200 210 0 631 6/27/2018 2250 210 0 418.5 6/26/2018 2250 210 0 461.5 6/25/2018 2250 180 0 450 6/24/2018 2250 150 0 816.8 6/23/2018 2250 170 0 710 6/22/2018 2200 210 0 399.4 6/21/2018 2225 220 0 555 6/20/2018 2225 200 0 554 6/19/2018 2200 205 0 486 6/18/2018 2200 145 0 896 6/17/2018 2200 200 0 494 6/16/2018 2200 150 0 909 6/15/2018 2225 225 0 521 6/14/2018 2200 220 0 572 6/13/2018 2200 210 0 550.1 6/12/2018 2200 240 0 476.38 6/11/2018 2150 200 0 790.16 6/10/2018 2150 200 0 568.3 6/9/2018 2150 200 0 509.8 6/8/2018 2150 230 0 493.5 6/7/2018 2200 210 0 393 6/6/2018 2200 200 0 537 6/5/2018 2200 200 0 546 6/4/2018 2200 205 0 492 6/3/2018 2200 210 0 565 6/2/2018 2200 210 0 650 6/1/2018 2200 210 0 532 5/31/2018 2150 220 0 468 5/30/2018 2150 220 0 435 5/29/2018 2150 220 0 420 5/28/2018 2150 220 0 484 5/27/2018 2150 220 0 476 5/26/2018 2150 210 0 590 5/25/2018 2150 210 0 440 5/24/2018 2150 220 0 315 5/23/2018 2200 215 0 425 5/22/2018 2200 210 0 510 5/21/2018 2200 215 0 381 5/20/2018 2200 210 0 484 5/19/2018 2200 205 0 448 5/18/2018 2175 210 0 514 5/17/2018 2175 220 0 330 5/16/2018 2200 215 0 391 5/15/2018 2200 205 0 388 5/14/2018 2200 200 0 481 5/13/2018 2200 200 0 500 5/12/2018 2200 210 0 506 5/11/2018 2150 210 0 456 5/10/2018 2150 205 0 410 5/9/2018 2150 210 0 530 5/8/2018 2150 220 0 390 5/7/2018 2150 220 0 462 5/6/2018 2150 220 0 575 5/5/2018 2150 230 0 339 5/4/2018 2150 240 0 509 5/3/2018 2150 200 0 0 5/2/2018 2150 200 0 219.94 5/1/2018 2150 200 0 325 4/30/2018 2150 200 0 390.75 4/29/2018 2150 200 0 446.1 4/28/2018 2150 190 0 521.4 4/27/2018 2100 190 0 454.65 4/26/2018 2200 200 0 264.5 4/25/2018 2200 190 0 516 4/24/2018 2150 200 0 522 4/23/2018 2150 210 0 452 4/22/2018 2000 220 0 151 4/21/2018 2150 200 0 484 4/20/2018 2175 190 0 520 4/19/2018 2150 195 0 251 4/18/2018 2100 230 0 327 4/17/2018 2100 190 0 230 4/16/2018 2100 190 0 530 4/15/2018 2100 180 0 465 4/14/2018 2100 190 0 646 4/13/2018 2100 200 0 435 4/12/2018 2150 190 0 425 4/11/2018 2150 185 0 465 4/10/2018 2125 190 0 427 4/9/2018 2150 160 0 673 4/8/2018 2050 190 0 425 4/7/2018 2100 180 0 395 4/6/2018 2150 175 0 607 4/5/2018 2100 205 0 323 4/4/2018 2100 190 0 325 4/3/2018 2100 180 0 756.59 4/2/2018 2100 180 0 409 4/1/2018 2000 200 0 241.5 3/31/2018 2100 200 0 265 3/30/2018 2100 150 0 621 3/29/2018 2150 200 0 433 3/28/2018 2100 190 0 450 3/27/2018 2100 180 0 335 3/26/2018 2175 180 0 590 3/25/2018 2150 185 0 495 3/24/2018 2100 180 0 450 3/23/2018 2125 200 0 435 3/22/2018 2100 205 0 305 3/21/2018 2100 120 0 360 3/20/2018 2100 180 0 603.5 3/19/2018 2100 200 0 308.5 3/18/2018 2100 170 0 532 3/17/2018 2100 200 0 446.5 3/16/2018 2100 170 0 537 3/15/2018 2100 160 0 380 3/14/2018 2100 190 0 560 3/13/2018 2100 165 0 385 3/12/2018 2100 165 0 367 3/11/2018 2150 155 0 477 3/10/2018 2150 160 0 499 3/9/2018 2150 160 0 490 3/8/2018 2150 165 0 495 3/7/2018 2450 180 0 505 3/6/2018 2100 160 0 500 3/5/2018 2100 180 0 523 3/4/2018 2100 160 0 415 3/3/2018 2100 180 0 485 3/2/2018 2100 170 0 400 3/1/2018 2100 170 0 375 2/28/2018 2100 175 0 470 2/27/2018 2100 175 0 485 2/26/2018 2100 175 0 460 2/25/2018 2100 175 0 500 2/24/2018 2100 175 0 458 2/23/2018 2100 175 0 475 2/22/2018 2100 175 0 463 2/21/2018 2100 170 0 390 2/20/2018 2100 180 0 348 2/19/2018 2100 170 0 407 2/18/2018 2050 160 0 385 2/17/2018 2050 100 0 603 2/16/2018 1806 190 0 415 2/15/2018 2000 190 0 410 2/14/2018 2050 170 0 460 2/13/2018 2000 150 0 520 2/12/2018 1900 150 0 335 2/11/2018 1900 190 0 573 2/10/2018 1950 200 0 315 2/9/2018 1950 215 0 247 2/8/2018 2000 225 0 350 2/7/2018 2000 210 0 255 2/6/2018 2000 160 0 305 2/5/2018 1950 210 0 170 2/4/2018 2000 190 0 340 2/3/2018 1950 200 0 293 2/2/2018 1950 210 0 310 2/1/2018 2000 210 0 295 1/31/2018 1925 220 0 245 1/30/2018 1950 195 0 275 1/29/2018 1900 195 0 320 1/28/2018 1950 200 0 342 1/27/2018 1850 190 0 313 1/26/2018 1900 205 0 135 1/25/2018 2000 210 0 455 1/24/2018 1950 210 0 270 1/23/2018 2000 220 0 250 1/22/2018 2000 220 0 320 1/21/2018 1950 200 0 265 1/20/2018 2000 230 0 355 1/19/2018 1778 220 0 180 1/18/2018 2000 220 0 450 1/17/2018 1950 225 0 280 1/16/2018 1950 210 0 300 1/15/2018 2000 225 0 462 1/14/2018 1875 215 0 183 1/13/2018 1925 220 0 225 1/12/2018 2000 205 0 375 1/11/2018 1975 215 0 429 1/10/2018 2000 210 0 330 1/9/2018 2000 200 0 255 1/8/2018 2000 200 0 460 1/7/2018 2000 220 0 345 1/6/2018 2000 220 0 390 1/5/2018 1900 220 0 359 1/4/2018 2000 220 0 208 1/3/2018 1975 200 0 303 1/2/2018 1950 220 0 305 1/1/2018 1800 205 0 214 Hilcorp Alaska, LLC April 9, 2019 Mr. Chris Wallace Alaska Oil & Gas Conservation Commission 333 W. 7'h Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: DEEP CREEK UNIT, HAPPY VALLEY FIELD 2017 ANNUAL Disposal Report for NNA#1 Dear Mr. Wallace: Post OMce Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8322 Fax: 907/777-8580 MAY 0 8 2019 AOGCC Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2017 as governed by AOGCC Disposal Injection Order #28A, rule #5. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2017 injection history for the NNA #1 well bore. Specific items for this reporting period: The fluids injected into the NNA #1 were composed of -98% produced water from Happy Valley wells • On May 17, 2017 a successful MIT was witnessed by AOGCC representative Mr. Jeff Jones on the NNA # 1. • The next MIT for the NNA #I is scheduled for May 2019. • The average injection pressure in 2017 was approximately 2,100 psig. • The maximum injection pressure in 2017 was 3,000 psig which is below the permitted 4,000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 4,000 BPD at 2.5 BPM of a slurry laden fluid. In contrast, the well injection volumes during 2017 were no more than 1,085 BPD at no more than 1.0 BPM instantaneous injection rates. • The injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore, and operating conditions. Sin7Z4onvy McConkey Reservoir Engineer Attachment 1—NNA#1 Injection rates and pressures 2017 3000 2500 2000 1500 1000 500 0 DCU NNA 001 WDW 91/2017 0212D17 0312017 VV2017 0512017 06/2217 0712017 R/2017 09%2017 10/2017 11,1017 17/2017 Tub' — Im — OA _., Water Injection 1200 10.00 800 600 400 X00 Well: NNA #1 Desc: Disposal Permit to drill: 2012150 Admin Approval: DIO #28A API; 50-133-20507-00-00 Date Range: 01/01/2017 -12/31/2017 Date Tubing IA OA Water Injection 12/31/2017 2000 210 0 426 12/30/2017 2000 210 0 170 12/29/2017 1950 200 0 310 12/28/2017 2000 210 0 370 12/27/2017 2000 220 0 320 12/26/2017 2000 220 0 350 12/25/2017 1793 220 0 395 12/24/2017 1782 210 0 375 12/23/2017 2000 210 0 350 12/22/2017 2000 160 0 380 12/21/2017 1950 200 0 330 12/20/2017 1950 220 0 430 12/19/2017 2000 220 0 270 12/18/2017 1900 220 0 360 12/17/2017 1900 220 0 270 12/16/2017 1791 240 0 270 12/15/2017 1800 230 0 275 12/14/2017 1900 220 0 170 12/13/2017 1900 230 0 225 12/12/2017 1975 205 0 335 12/11/2017 1950 200 0 310 12/10/2017 2000 185 0 383 12/9/2017 1975 115 0 427 12/8/2017 2000 195 0 620 12/7/2017 1900 150 0 470 12/6/2017 2000 205 0 390 12/5/2017 2000 200 0 475 12/4/2017 1975 185 0 450 12/3/2017 2000 195 0 551 12/2/2017 1975 215 0 506 12/1/2017 1875 140 0 192 11/30/2017 2000 195 0 732 11/29/2017 2000 180 0 380 11/28/2017 2000 180 0 460 11/27/2017 2000 150 0 380 11/26/2017 2000 190 0 490 11/25/2017 2050 190 0 520 11/24/2017 2000 180 0 380 11/23/2017 1950 150 0 528 11/22/2017 1950 195 0 292 11/21/2017 1950 200 0 440 11/20/2017 1800 215 0 360 11/19/2017 1900 210 0 256 11/18/2017 1900 220 0 266 11/17/2017 1900 205 0 249 11/16/2017 1900 190 0 380 11/15/2017 1900 190 0 260 11/14/2017 1950 195 0 400 11/13/2017 1900 190 0 325 11/12/2017 1900 180 0 390 11/11/2017 1900 200 0 380 11/10/2017 1950 210 0 400 11/9/2017 1930 200 0 540 11/8/2017 1950 180 0 541 11/7/2017 1900 200 0 390 11/6/2017 1825 220 0 470 11/5/2017 1875 230 0 480 11/4/2017 1900 210 0 470 11/3/2017 1900 215 0 620 11/2/2017 1900 240 0 445 11/1/2017 1900 250 0 322 10/31/2017 1900 220 0 236.5 10/30/2017 1900 220 0 290 10/29/2017 1950 200 0 236 10/28/2017 1900 200 0 567 10/27/2017 1850 250 0 201.5 10/26/2017 1850 210 0 316.5 10/25/2017 1800 235 0 278 10/24/2017 1850 225 0 307 10/23/2017 1850 235 0 255 10/22/2017 1800 225 0 340 10/21/2017 1800 225 0 275 10/20/2017 1800 210 0 300 10/19/2017 1800 210 0 395 10/18/2017 1650 210 302 10/17/2017 1800 220 262 10/16/2017 1800 205 325 10/15/2017 1550 200 81 10/14/2017 1800 190 0 215 10/13/2017 1800 200 0 246 10/12/2017 1825 185 0 315 10/11/2017 1875 160 0 465 10/10/2017 1900 150 0 703 10/9/2017 1840 170 0 625 10/8/2017 1850 185 0 402 10/7/2017 1800 210 0 580 10/6/2017 1825 200 0 356 10/5/2017 1800 205 0 400 10/4/2017 1800 200 0 500 10/3/2017 1700 200 0 500 10/2/2017 1700 200 0 320 10/1/2017 1750 200 0 250 9/30/2017 1750 200 0 365 9/29/2017 1900 200 500 9/28/2017 1840 185 0 340 9/27/2017 1840 150 0 650 9/26/2017 1825 190 0 560 9/25/2017 1800 200 0 460 9/24/2017 1825 190 0 543 9/23/2017 1850 190 0 580 9/22/2017 1800 205 0 556 9/21/2017 1800 240 0 325 9/20/2017 1800 240 0 300 9/19/2017 1800 230 0 380 9/18/2017 1750 230 0 300 9/17/2017 1800 230 0 220 9/16/2017 1900 220 0 250 9/15/2017 1800 250 0 280 9/14/2017 1650 240 0 340 9/13/2017 1700 240 0 360 9/12/2017 1800 240 0 153 9/11/2017 1800 250 0 342 9/10/2017 1800 255 0 240 9/9/2017 1850 245 0 387 9/8/2017 2050 240 0 367 9/7/2017 2100 260 216 9/6/2017 2200 255 440 9/5/2017 1600 255 70 9/4/2017 1550 250 0 9/3/2017 1800 250 400 9/2/2017 2300 250 0 360 9/1/2017 2200 255 0 260 8/31/2017 2300 255 0 275 8/30/2017 2000 265 0 345 8/29/2017 2000 255 0 315 8/28/2017 2000 260 0 339 8/27/2017 1900 260 0 231 8/26/2017 2000 270 0 275 8/25/2017 2000 270 0 228 8/24/2017 2000 275 0 287 8/23/2017 2100 270 0 340 8/22/2017 2100 280 0 370 8/21/2017 2100 290 0 220 8/20/2017 2100 270 0 380 8/19/2017 2100 260 0 420 8/18/2017 2100 220 0 554 8/17/2017 2100 230 0 170 8/16/2017 2050 270 0 400 8/15/2017 2100 270 0 350 8/14/2017 2100 270 0 580 8/13/2017 2100 270 0 397 8/12/2017 2100 270 0 428 8/11/2017 2000 290 0 225 8/10/2017 2100 280 0 350 8/9/2017 1900 290 0 320 8/8/2017 2000 290 0 300 8/7/2017 2000 300 0 360 8/6/2017 2000 300 0 270 8/5/2017 2000 290 0 310 8/4/2017 2000 290 0 285 8/3/2017 1900 280 0 280 8/2/2017 1900 255 0 258 8/1/2017 1950 260 0 355 7/31/2017 1975 240 0 342 7/30/2017 2000 210 0 630 7/29/2017 1950 215 0 443 7/28/2017 1950 240 0 405 7/27/2017 2000 260 0 490 7/26/2017 1975 225 0 524 7/25/2017 2000 230 0 550 7/24/2017 1950 270 0 405 7/23/2017 1950 255 0 365 7/22/2017 2000 240 0 305 7/21/2017 2000 230 0 440 7/20/2017 2000 180 0 531 7/19/2017 2000 210 0 552 7/18/2017 2000 175 0 718 7/17/2017 1950 200 0 656 7/16/2017 1950 240 0 404 7/15/2017 1950 230 0 646 7/14/2017 1900 260 0 359 7/13/2017 1900 295 0 310 7/12/2017 280 295 7/11/2017 260 350 7/10/2017 280 280 7/9/2017 280 290 7/8/2017 280 360 7/7/2017 280 390 7/6/2017 280 255 7/5/2017 1900 265 0 335 7/4/2017 1900 250 0 377 7/3/2017 1900 250 0 363 7/2/2017 1900 235 0 325 7/1/2017 1850 240 0 421 6/30/2017 1900 235 0 464 6/29/2017 1900 250 0 315 6/28/2017 1900 230 0 425 6/27/2017 2000 220 0 460 6/26/2017 2000 220 0 535 6/25/2017 2100 220 0 480 6/24/2017 2200 230 0 455 6/23/2017 2100 240 0 410 6/22/2017 2300 110 0 550 6/21/2017 2300 260 0 411 6/20/2017 2300 270 0 339 6/19/2017 2300 275 0 330 6/18/2017 2300 275 0 345 6/17/2017 2300 270 0 387 6/16/2017 2300 265 0 348 6/15/2017 2300 270 0 367 6/14/2017 2200 280 0 395 6/13/2017 2000 280 0 320 6/12/2017 2400 280 0 365 6/11/2017 2100 280 0 420 6/10/2017 2600 290 0 350 6/9/2017 2600 290 0 435 6/8/2017 2500 280 0 285 6/7/2017 2550 275 0 395 6/6/2017 2560 280 0 328 6/5/2017 2500 270 0 297 6/4/2017 2500 280 0 458 6/3/2017 2600 240 0 212,4 6/2/2017 2500 260 0 412 6/1/2017 2500 256 0 345 5/31/2017 2600 250 0 340 5/30/2017 2550 240 0 335 5/29/2017 2550 230 0 270 5/28/2017 2600 220 0 365 5/27/2017 2600 50 0 1085 5/26/2017 2550 230 0 525 5/25/2017 2500 240 0 382 5/24/2017 2500 150 0 751 5/23/2017 2500 265 0 377 5/22/2017 2500 200 0 770 5/21/2017 2475 200 0 357 5/20/2017 2475 250 0 649 5/19/2017 2450 300 0 324 5/18/2017 2425 280 0 285 5/17/2017 2400 260 0 520 5/16/2017 2400 310 0 370 5/15/2017 2400 320 0 280 5/14/2017 2300 330 0 410 5/13/2017 2400 320 0 360 5/12/2017 2400 360 0 260 5/11/2017 2300 330 0 188 5/10/2017 2350 350 0 197 5/9/2017 2300 340 0 155 5/8/2017 2350 345 0 303 5/7/2017 2345 340 0 277 5/6/2017 2350 350 0 235 5/5/2017 2350 360 0 148 5/4/2017 2300 355 0 147 5/3/2017 2400 360 0 170 5/2/2017 2300 320 0 170 5/1/2017 2100 330 0 100 4/30/2017 2200 330 0 140 4/29/2017 2400 320 0 235 4/28/2017 2400 310 0 305 4/27/2017 2200 315 0 220 4/26/2017 2300 335 0 280 4/25/2017 2300 310 0 110 4/24/2017 2350 305 0 370 4/23/2017 2350 330 0 205 4/22/2017 2300 335 0 203 4/21/2017 2375 340 0 214 4/20/2017 2350 330 0 148 4/19/2017 2400 320 0 345 4/18/2017 2400 310 0 175 4/17/2017 2400 310 0 270 4/16/2017 2400 300 0 250 4/15/2017 2300 310 0 235 4/14/2017 2400 310 0 320 4/13/2017 2400 310 0 250 4/12/2017 2400 300 0 231 4/11/2017 2400 310 0 261 4/10/2017 2400 310 0 238 4/9/2017 2400 300 0 293 4/8/2017 2375 310 0 192 4/7/2017 2400 280 0 471 4/6/2017 2400 280 0 329 4/5/2017 2400 280 0 335 4/4/2017 2400 270 0 420 4/3/2017 2350 270 0 405 4/2/2017 2400 280 0 345 4/1/2017 2400 290 0 375 3/31/2017 2400 250 0 440 3/30/2017 2350 290 0 275 3/29/2017 2300 260 0 335 3/28/2017 2350 255 0 332 3/27/2017 2300 265 0 347 3/26/2017 2300 255 0 243 3/25/2017 2300 320 0 193 3/24/2017 2300 315 0 175 3/23/2017 2300 315 0 190 3/22/2017 2200 300 0 190 3/21/2017 2300 290 0 300 3/20/2017 2200 310 0 160 3/19/2017 2300 310 0 220 3/18/2017 2300 310 0 220 3/17/2017 2400 310 0 240 3/16/2017 2100 320 0 210 3/15/2017 2250 300 0 135 3/14/2017 2400 310 0 215 3/13/2017 2300 295 0 190 3/12/2017 2300 320 0 221 3/11/2017 2310 310 0 145 3/10/2017 2300 300 0 225 3/9/2017 2300 300 0 100 3/8/2017 2400 290 0 320 3/7/2017 2400 300 0 220 3/6/2017 2300 310 0 190 3/5/2017 2300 300 0 124 3/4/2017 2300 300 0 310 3/3/2017 2200 250 0 270 3/2/2017 2300 310 0 201 3/1/2017 2200 295 0 23 2/28/2017 2245 290 0 80 2/27/2017 2260 135 0 83 2/26/2017 2265 220 0 255 2/25/2017 2400 185 0 357 2/24/2017 3000 225 0 488 2/23/2017 2400 230 0 275 2/22/2017 2400 230 0 290 2/21/2017 2400 230 0 390 2/20/2017 2400 230 0 395 2/19/2017 2400 230 0 440 2/18/2017 2400 210 0 630 2/17/2017 2350 225 0 335 2/16/2017 2380 225 0 418 2/15/2017 2380 230 0 418 2/14/2017 2350 230 0 433 2/13/2017 2350 220 0 333 2/12/2017 2350 215 0 435 2/11/2017 2350 250 0 403 2/10/2017 2350 240 0 432 2/9/2017 2350 260 0 360 2/8/2017 2300 260 0 390 2/7/2017 2300 270 0 400 2/6/2017 2300 280 0 355 2/5/2017 2300 290 0 310 2/4/2017 2300 300 0 310 2/3/2017 2300 290 0 440 2/2/2017 2250 310 0 323 2/1/2017 2250 320 0 200 1/31/2017 2250 325 0 277 1/30/2017 2200 310 0 146 1/29/2017 2250 290 0 327 1/28/2017 1850 330 0 212 1/27/2017 2225 330 0 193 1/26/2017 2200 330 0 162 1/25/2017 2200 330 0 190 1/24/2017 2250 360 0 250 1/23/2017 1300 330 0 0 1/22/2017 2200 310 0 275 1/21/2017 2250 320 0 180 1/20/2017 2200 330 0 170 1/19/2017 2300 320 0 140 1/18/2017 2200 320 0 173 1/17/2017 2200 330 0 202 1/16/2017 2200 340 0 162 1/15/2017 2200 330 0 134 1/14/2017 2200 320 0 146 1/13/2017 2200 325 0 337 1/12/2017 2150 350 0 90 1/11/2017 2200 320 0 165 1/10/2017 2300 320 0 235 1/9/2017 2400 320 0 220 1/8/2017 2300 310 0 185 1/7/2017 2250 290 0 345 1/6/2017 2250 330 0 230 1/5/2017 2250 330 0 383 1/4/2017 2150 340 0 5 1/3/2017 2200 340 0 177 1/2/2017 2250 315 0 252 1/1/2017 2250 360 0 201 2121.26 RECEIVED Hilcorp Alaska, LLC March 20, 2017 Mr. Guy Schwartz Alaska Oil & Gas Conservation Commission 333 W. 7' Avenue, Suite 100 Anchorage, Alaska 99501-3539 LIAR 31 2017 Re: DEEP CREEK UNIT, HAPPY VALLEY FIELD 2016 ANNUAL Disposal Report for NNA#1 Dear Mr. Schwartz: Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone:907/777-8322 Fax: 907/777-8580 Attached is the Annual Report of UIC Class II disposal operations for the NNA # 1 wellbore for 2016 as governed by AOGCC Disposal Injection Order #28A, rule #5. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2016 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were composed of-98% produced water from Happy Valley wells • On May 22, 2015 a successful MIT was witnessed by the SOA on the NNA #1 • The next MIT for the NNA #1 is scheduled for May, 2017 • The maximum injection pressure in 2016 was 2330 psig which is below the permitted 4,000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 4,000 BPD at 2.5 BPM of a slurry laden fluid. In contrast, the well injection volumes during 2016 were no more than 795 BPD at no more than 1.0 BPM instantaneous injection rates. • The injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore, and operating conditions. Sincerely, Trudi Hallett Reservoir Engineer Jim Young Reservoir Engineer Attachment 1 — NNA# 1 Injection rates and pressures 2016 SEP 22 2016 Hilcorp Alaska, LLC Sept 20, 2016 Mr. Guy Schwartz Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 DEEP CREEK UNIT HAPPY VALLEY FIELD STATE OF ALASKA 2015 ANNUAL Disposal Report for NNA#1 Dear Mr. Schwartz: Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone:907/777-8414 Fax:907/777-8580 dduffy@hilcorp.com Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2015. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2015 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were composed of —98% produced water from Happy Valley wells • On May 22, 2015 a successful MIT was witnessed by the SOA on the NNA #1 • The next MIT for the NNA #1 is scheduled for May, 2017 • The average monthly injection volume into the NNA #1, during the reporting time period, was approximately 7,100 barrels/month • The average injection pressure in 2015 was approximately 1,922 psig • The maximum injection pressure in 2015 was 3,700 psig which is below the permitted 4,000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 4,000 BPD at 2.5 BPM of a slurry laden fluid. In contrast, the well injection volumes during 2015 were no more than 680 BPD at no more than 1.0 BPM instantaneous injection rates. • The injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore, and operating conditions. The reporting time period covers one calendar year. This is consistent with Rule #5 of the AOGCC Disposal Injection Order #28A. Please contact Jason Ewing with any questions regarding this report at 777-8441. Sincerely, J son Ewing Reservoir Engineer Cc: Larry Greenstein Field Well Files, Hilcorp Page 2 DCU NNA 001 WDW Cumulative Gas Production:.0 MMcf -- Oil Production:.0 Mbbl -- Water Production:.0 Mbbl -- Water Injection: 85.4 Mbbl i 10' 01.�2015 02{2015 0312015 04/2015 05/2015 06,2015 07!2015 08/2015 09I2015 MQ015 11i2015 1212015 —' later Injection (BWPD) — Tubing Pressure (psig) Date 1/1/2015 1/2/2015 1/3/2015 1/4/2015 1/5/2015 1/6/2015 1/7/2015 1/8/2015 1/9/2015 1/10/2015 1/11/2015 1/12/2015 1/13/2015 1/14/2015 1/15/2015 1/16/2015 1/17/2015 1/18/2015 1/19/2015 1/20/2015 1/21/2015 1/22/2015 1/23/2015 Water Injection (BWPD) Tubing Pressure (psig) 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 250i iX,Clf] 150": 1/24/2015 1/25/2015 1/26/2015 1/27/2015 1/28/2015 1/29/2015 1/30/2015 1/31/2015 2/1/2015 2/2/2015 2/3/2015 2/4/2015 2/5/2015 2/6/2015 2/7/2015 2/8/2015 2/9/2015 2/10/2015 2/11/2015 2/12/2015 2/13/2015 2/14/2015 2/15/2015 2/16/2015 2/17/2015 2/18/2015 2/19/2015 2/20/2015 2/21/2015 2/22/2015 2/23/2015 2/24/2015 2/25/2015 2/26/2015 2/27/2015 2/28/2015 3/1/2015 3/2/2015 3/3/2015 3/4/2015 3/5/2015 3/6/2015 3/7/2015 3/8/2015 3/9/2015 3/10/2015 3/11/2015 3/12/2015 3/13/2015 3/14/2015 3/15/2015 3/16/2015 3/17/2015 3/18/2015 3/19/2015 3/20/2015 3/21/2015 3/22/2015 3/23/2015 3/24/2015 3/25/2015 3/26/2015 3/27/2015 3/28/2015 3/29/2015 90 405 415 493 425 410 98 242 238 205 380 99 130 259 160 860 860 860 860 860 860 860 860 860 860 860 860 860 860 860 820 820 820 820 820 820 820 760 1200 1200 2850 3000 3300 3650 3300 3400 3350 3350 3200 3200 2300 2280 2280 2175 2175 2150 2175 2175 3100 3200 3450 3450 3450 2300 2250 2150 2150 2050 2050 2050 2050 2050 2050 2050 1750 1750 1750 1710 1710 1710 3/30/2015 1710 3/31/2015 1675 4/l/2015 1675 4/2/2015 1675 4/3/2015 1625 4/4/2015 1625 4/5/2015 1625 4/6/2015 1625 4/7/2015 1550 4/8/2015 1550 4/9/2015 1550 4/10/2015 1550 4/11/2015 1550 4/12/2015 1550 4/13/2015 1550 4/14/2015 1550 4/15/2015 1550 4/16/2015 53 1550 4/17/2015 50 3005 4/18/2015 64 3400 4/19/2015 69 3600 4/20/2015 3650 4/21/2015 105 3650 4/22/2015 3650 4/23/2015 4/24/2015 4/25/2015 4/26/2015 4/27/2015 4/28/2015 4/29/2015 4/30/2015 5/l/2015 1500 5/2/2015 1500 5/3/2015 1500 5/4/2015 1500 5/5/2015 1500 5/6/2015 1500 5/7/2015 1500 5/8/2015 54 1500 5/9/2015 5/10/2015 5/11/2015 1680 5/12/2015 1680 5/13/2015 1680 5/14/2015 1680 5/15/2015 1680 5/16/2015 1680 5/17/2015 109 3600 5/18/2015 67 3650 5/19/2015 83 3650 5/20/2015 77 3650 5/21/2015 99 3650 5/22/2015 65 3500 5/23/2015 106 3500 5/24/2015 80 2800 5/25/2015 88 3400 5/26/2015 96 3200 5/27/2015 86 3350 5/28/2015 177 3200 5/29/2015 280 3650 5/30/2015 310 3650 5/31/2015 256 3600 6/1/2015 276 3650 6/2/2015 313 3600 6/3/2015 263 3600 6/4/2015 210 3600 6/5/2015 230 3600 6/6/2015 532 3600 6/7/2015 392 3700 6/8/2015 225 3650 6/9/2015 484 3650 6/10/2015 365 3670 6/11/2015 240 3650 6/12/2015 194 3650 6/13/2015 275 1325 6/14/2015 400 1450 6/15/2015 178 1500 6/16/2015 260 1450 6/17/2015 489 1450 6/18/2015 290 1550 6/19/2015 450 1600 6/20/2015 467 1600 6/21/2015 395 1600 6/22/2015 468 1550 6/23/2015 561 1600 6/24/2015 679 1600 6/25/2015 401 1650 6/26/2015 501 1650 6/27/2015 434 1700 6/28/2015 559 1700 6/29/2015 426 1750 6/30/2015 418 1750 7/1/2015 544 1750 7/2/2015 406 1800 7/3/2015 441 1800 7/4/2015 485 1750 7/5/2015 474 1800 7/6/2015 509 1800 7/7/2015 435 1800 7/8/2015 473 1800 7/9/2015 399 1800 7/10/2015 422 1800 7/11/2015 310 1800 7/12/2015 491 1800 7/13/2015 505 1800 7/14/2015 491 1800 7/15/2015 392 1800 7/16/2015 341 1900 7/17/2015 302 1800 7/18/2015 284 1600 7/19/2015 314 1800 7/20/2015 405 1850 7/21/2015 401 1850 7/22/2015 537 1800 7/23/2015 461 1850 7/24/2015 449 1850 7/25/2015 53 1850 7/26/2015 593 1850 7/27/2015 569 1850 7/28/2015 456 1850 7/29/2015 127 1850 7/30/2015 486 1850 7/31/2015 390 1800 8/1/2015 490 1850 8/2/2015 465 1850 8/3/2015 460 1850 8/4/2015 370 1850 8/5/2015 325 1825 8/6/2015 1200 8/7/2015 1000 8/8/2015 950 8/9/2015 900 8/10/2015 850 8/11/2015 825 8/12/2015 810 8/13/2015 800 8/14/2015 450 750 8/15/2015 509 1750 8/16/2015 397 1750 8/17/2015 488 1750 8/18/2015 447 1850 8/19/2015 537 1850 8/20/2015 172 1850 8/21/2015 512 1850 8/22/2015 342 1900 8/23/2015 558 1900 8/24/2015 402 1900 8/25/2015 404 1900 8/26/2015 404 1900 8/27/2015 490 1900 8/28/2015 398 1950 8/29/2015 484 1900 8/30/2015 470 1950 8/31/2015 445 1950 9/1/2015 405 1950 9/2/2015 457 1950 9/3/2015 330 1950 9/4/2015 475 1950 9/5/2015 415 1900 9/6/2015 465 1900 9/7/2015 510 1900 9/8/2015 426 1950 9/9/2015 377 1925 9/10/2015 425 1925 9/11/2015 400 1925 9/12/2015 420 1925 9/13/2015 415 1925 9/14/2015 425 1925 9/15/2015 665 1925 9/16/2015 505 1925 9/17/2015 415 1925 9/18/2015 460 1925 9/19/2015 430 1925 9/20/2015 415 1950 9/21/2015 355 1950 9/22/2015 550 1950 9/23/2015 330 1950 9/24/2015 375 1950 9/25/2015 381 1950 9/26/2015 472 1950 9/27/2015 480 1950 9/28/2015 425 1950 9/29/2015 450 1950 9/30/2015 461 1950 10/1/2015 235 1950 10/2/2015 330 1900 10/3/2015 558 1900 10/4/2015 358 2000 10/5/2015 321 2000 10/6/2015 405 2000 10/7/2015 311 2000 10/8/2015 494 1950 10/9/2015 410 1950 10/10/2015 470 1950 10/11/2015 420 1950 10/12/2015 570 1950 10/13/2015 400 1950 10/14/2015 485 1950 10/15/2015 385 1950 10/16/2015 405 2000 10/17/2015 450 2000 10/18/2015 455 2000 10/19/2015 505 2000 10/20/2015 475 2000 10/21/2015 350 2000 10/22/2015 440 2000 10/23/2015 523 2000 10/24/2015 407 2000 10/25/2015 313 2000 10/26/2015 510 2000 10/27/2015 425 2025 10/28/2015 435 2000 10/29/2015 346 2050 10/30/2015 395 2000 10/31/2015 484 2000 11/1/2015 215 2000 11/2/2015 584 2000 11/3/2015 160 2000 11/4/2015 532 2000 11/5/2015 479 2050 11/6/2015 305 2055 11/7/2015 385 2095 11/8/2015 150 2060 11/9/2015 209 2080 11/10/2015 120 2025 11/11/2015 245 2045 11/12/2015 310 2010 11/13/2015 205 1990 11/14/2015 1900 11/15/2015 80 1900 11/16/2015 140 1900 11/17/2015 160 1350 11/18/2015 165 1350 11/19/2015 160 2000 11/20/2015 150 2215 11/21/2015 230 2020 11/22/2015 243 1900 11/23/2015 180 1900 11/24/2015 180 1900 11/25/2015 150 1900 11/26/2015 150 1900 11/27/2015 180 1900 11/28/2015 90 1900 11/29/2015 175 1900 11/30/2015 260 1900 12/1/2015 185 1900 12/2/2015 415 1900 12/3/2015 360 1250 12/4/2015 170 1925 12/5/2015 160 1995 12/6/2015 330 1930 12/7/2015 275 1930 12/8/2015 235 1950 12/9/2015 220 1970 12/10/2015 250 1910 12/11/2015 55 1920 12/12/2015 336 2000 12/13/2015 410 2000 12/14/2015 505 2100 12/15/2015 580 2100 12/16/2015 380 2100 12/17/2015 500 2100 12/18/2015 585 2000 12/19/2015 362 2050 12/20/2015 583 2000 12/21/2015 480 2050 12/22/2015 495 2100 12/23/2015 275 2100 12/24/2015 410 2050 12/25/2015 420 2100 12/26/2015 550 2025 12/27/2015 450 2100 12/28/2015 365 2100 12/29/2015 550 2050 12/30/2015 424 2025 12/31/2015 565 2025 Hilcorp Alaska, LLC June 3, 2014 Mr. Guy Schwartz Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 DEEP CREEK UNIT HAPPY VALLEY FIELD STATE OFALASKA 2013 ANNUAL Disposal Report for NNA#1 Dear Mr. Schwartz: JUN 0 5 2014 A nG VC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone:907/777-8414 Fax: 907/777-8580 dduffy@hilcorp.com PT b zo 12t s® b1Q �gA F,W ; !deep cf-e elk Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2013. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2013 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were produced water and drilling fluids extracted from mud from the Happy Valley field. • On September 27, 2011 a successful MIT was witnessed by the SOA on this well. • The average monthly injection volume into the NNA #1, during the reporting time period, was approximately 222 barrels/month. January included more injection days due to drilling fluids extracted from mud used on the last of the three drill wells in 2012. The water rates fluctuated from 0- 2,660 bbl water each month. • There was no injection of produced water or other fluids during February through December 2013. Produced water from Happy Valley field began to be trucked to the Kenai Gas Field disposal facility starting in February 2013. • The average injection pressure was approximately 1,438 psig which is below the permitted 4000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 4000 BPD at 2.5 BPM of a slurry laden fluid. In contrast, the well injection volumes during 2013 were no more than 520 BPD at no more than 1.0 BPM injection rates. The injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore, and operating conditions. The reporting time period covers one calendar year. This is consistent with Rule #5 of the AOGCC Disposal Injection Order #28A. Please contact Chris Kanyer with any questions regarding this report at 777-8377. Sincerely, 1 Chris Kanyer Reservoir Engineer Cc: Larry Greenstein Field Well Files, Hilcorp Page 2 Hilcorp Alaska, LLC Deep Creek Unit - NNA#1 2013 Injection Summary Days On Tubing Press Casing Press Daily Avg Inj Tota � � Monthly Inj I Cum Inj Date Max, psig Avg psig Max,psig Avg psig Max (Bbl) Avg (Bbl) Bbl Bbl Dec-12 12 3,050 2,522.6 520 472.3 510 237.5 2850 102216 Jan-13 11 2,454 2,850.0 493 545.0 2,660 520 2660 104876 Feb-13 0 1,882 2,170.0 532 550.0 0 0.0 0 104876 Mar-13 0 1,588 1,745.0 5128 546.0 0 0.0 0 104876 Apr-13 0 1,431 1,645.0 0 0.0 0 104876 May-13 0 1,256 1,300.0 0 0.0 0 104876 Jun-13 0 1,167 1,225.0 533 545.0 0 0.0 0 104876 Jul-13 0 1,092 1,150.0 525 545.0 0 0.0 0 104876 Aug-13 0 1,080 1,100.0 545 545.0 0 0.0 0 104876 Sep-13 0 1,005 1,075.0 5145 545.0 0 0.0 0 104876 Oct-13 0 1,000 1,000.0 545 545.0 0 0.0 0 104876 Nov-13 0 996 1,000 $45 545.0 0 0.0 0 104876 Dec-13 0 995 995.0 545 545.0 0 0.0 0 104876 Page 3 r C ao v n ro LA n 't n w vo Ln LA 1 �l 0 0 r+ cn O 0 0 0 ,- 0 0 0 v w T IT W a F-� w D w a, w j c i w c N w D c 0� s w LA N w O w z 0 w rn N 0 0 N cv N w in o Ln o 0 0 0 0 0 0 0 0 w Ln 0 0 0 rJ 1� 3 Page 4 l ilcoi°p Alaska, LLC July 1, 2013 Mr. Guy Schwartz Alaska Oil & Gas Conservation Commission 333 W. 71h Avenue, Suite 100 Anchorage, Alaska 99501-3539 DEEP CREEK UNIT HAPPY VALLEY FIELD STATE OF ALASKA 2012 ANNUAL Disposal Report for NNA#1 Dear Mr. Schwartz: Post Office Box 244027 Anchorage, AK 99524-4017 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8414 Fax:907/777-8580 dduffy@hilcorp.ccm rrD 2U 21S0 61 o ), � A Fd4 Deep Cme K Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2012. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2012 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were produced water from the Happy Valley field. • On September 27, 2011 a successful MIT was witnessed by the SOA on this well. • The average monthly injection volume into the NNA #1, during the reporting time period, was approximately 599 barrels/month. Water is trucked every five to six weeks when approximately 400- 700 bbl water has accumulated. October through December included more injection days due to drilling fluids extracted from mud used on the three drill wells in 2012. The water rates fluctuated from 0-2,850 bbl water each month. • The average injection pressure was approximately 1,197 psig which is below the permitted 4000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes up to 4000 BPD at 2.5 BPM of a slurry laden fluid. In contrast, the well injection volumes during 2011 were no more than 694 BPD at no more than 1.0 BPM injection rates. • The injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore, and operating conditions. The reporting time period covers one calendar year. This is consistent with Rule #5 of the A®GCC Disposal Injection Order #28A. Please contact Chris Kanyer with any questions regarding this report at 777-8377. Sincerely, Chris Kanyer Reservoir Engineer Cc: Larry Greenstein Field Well Files, Hilcorp Page 2 Hilcorp Alaska, LLC Deep Creek Unit - NNA1 2012 Injection Summary Days On Tubing Press Casing Press Daily Avg Inj Tota I Monthly Inj Cum Inj Date Max, psig Avg psig Max, psig Avg psig Max (Bbl) Avg (Bbl) Bbl Bbl Dec-11 0 1000 899 500 500 0 0 0 94434 Jan-12 1 2,000 1,331.7 500 499.7 520 520 520 94954 Feb-12 0 2,350 1,068.3 510 501.S 0 0 0 94954 Mar-12 0 1,000 917.9 520 502.3 0 0 0 94954 Apr-12 0 1,075 938.7 520 503 0 0 0 94954 May-12 1 3,000 1,070.6 675 523.1 576 576 576 95530 Jun-12 0 1,000 899.3 530' 507.8 0 0 0 95530 Jul-12 2 1,950 982.3 540 515.8 432 384 768 96298 Aug-12 2 2,340 1,232.3 5701 527.4 694 419 838 97136 Sep-12 2 1,800 1,215.8 520 510 300 185 370 97506 Oct-12 3 2,850 1,226.8 52a 498.4 330 213.3 640 98146 Nov-12 5 3,250 1,253 529 498.7 320 244 1220 99366 Dec-12 12 3,050 2,522.6 526 472.3 510 237.5 2850 102216 Page 3 10 cii LT N. CnG (D i.r. r,j c Q 0 60 z 0 M Ln o 0 Page 4 • • Chevron David A. Cole Union Oil Company of California Technical Team Lead - Ops 3800 Centerpoint Dr., Suite 100 Anchorage, AK 99503 Tel 907 263 7805 Fax 907 263 7847 Email dcole @chevron.com f RECEIVED FEB 0 2 2012 January 30, 2012 Alaska tail & Gas Cons. Commission Anchorage Mr. Tom Maunder -- Alaska Oil & Gas Conservation Commission (AOGCC) � ZIZl 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: 2011 Annual Disposal Report for the NNA #1 Well in the Deep Creek Unit Zoi -Z Dear Mr. Maunder Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2011. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2011 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were produced water from the Happy Valley field. • On September 27, 2011 a successful MIT was witnessed by the SOA on this well. • The average monthly injection volume into the NNA #1, during the reporting time period, was approximately 353 barrels /month. Water is trucked every five to six weeks when approximately 400 -500 bbl water has accumulated, causing the water rate to fluctuate from 0 -800 bbl water each month. • The average injection pressure was approximately 1037 psig which is below the permitted 4000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore and operating conditions. Union Oil Company of California / A Chevron Company http: / /www.chevron.com • • Mr. Tom Maunder Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 The reporting time period covers one calendar year. This is consistent with Rule #5 of the AOGCC Disposal Injection Order #28A. As you are aware, Union sold its Cook Inlet Oil and Gas operations to Hilcorp Alaska LLC. The closing date was December 31, 2011. If you have any questions or concerns going forward about the enclosed information, please contact Larry Greenstein, who now works for Hilcorp. His phone number is 777 -8322. Sincerely, David A. Cole Technical Team Lead - Operations Attachment Union Oil Company of California / A Chevron Company http: / /www.chevron.com NNA #1 Injection Summary -2011 1400 — -- 6000 1200 - 5000 _c C O a 1000 - - 4000 E Aft 3 800 ... _a.__ _ a; H co a 3 000 c .a - 2000 • ._ I ::: c 0 200 - 1000 4) 0 - , _ . 0 ti ti ti ti N N ti N'' N ti ti ti" 1 a� <( i� _Na� Q'§ ' ` Sa \ ∎) P J% 5 ' 0 , ,e5-" Tubing Press Casing Press Total Monthly Inj • 0 Union Oil Company of California Deep Creek Unit - NNA #1 2011 Injection Summary Total Daily Avg Monthly Days On Tubing Press Casing Press Inj Inj Cum In] Date Max, psig Avg psig Max, psig Avg psig Bbl Bbl Bbl Dec -10 1 2300 1144.483 480 463 528 528 90371 Jan -11 1 2525 1155.833 488 642 570 570 90941 Feb -11 0 1025 978.1481 480 470 0 0 90941 Mar -11 3 3150 1125.667 480 460 311.3 934 91875 Apr -11 0 1510 1061.667 480 464 0 0 91875 May -11 2 2060 1060.9 460 455 232.5 465 92340 Jun -11 1 1175 915.9 460 457 60 60 92400 Jul -11 1 2200 972.7 460 452 168 168 92568 Aug -11 3 2600 1091.5 460 447 249.3 748 93316 Sep -11 2 1500 990.2 1780 630 35 70 93386 Oct -11 2 1900 1094.1 1790 633 384 768 94154 Nov -11 1 1710 988 500 493 280 280 94434 Dec -11 0 1000 899 500 500 0 0 94434 • • Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Thursday, February 02, 2012 3:50 PM I Z , To: Regg, James B (DOA) Cc: Brandenburg, Tim C Subject: RE: DIO #28A Annual Report - NNA #1 Attachments: DIO #35 Annual Report (IRU 13 -31); DIO #28A Annual Report - NNA #1 P'it 70/ - Jim, I believe Dave Cole was trying to complete these annual reports for the calendar year 2011 prior to his leaving Chevron's employment. It appears that in trying to get this done quickly (as he is gone now) he missed the specific requirements ✓ you highlighted in your e- mails. These deficiencies are being sent to Chevron for completion and I will follow up with them. Hilcorp plans to submit these reports by the July 1 dates covering the previous calendar year (ie by July 1, 2013 for the e 2012 calendar year) just as Chevron has been doing. Chevron was completing these reports (for DIO #28 & DIO #35) early just due to the special circumstance of the Cook Inlet Asset sale to Hilcorp. Sorry for the inconvenience. Larry From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, February 02, 2012 2:14 PM To: Larry Greenstein Subject: DIO #28A Annual Report - NNA #1 Report we received from David Cole is incomplete per requirements of DIO #28A, R . e 5. I've highlighted what is missing. RULE 5: Surveillance The operator shall obtain a baseline temperature log and a baseli - step rate test prior to initial injection. A subsequent temperature log must be perfo ► -d 1 month after injection begins to demonstrate the receiving zone of the injected flu' • s. Additional temperature survey requirements will be based on the results of the i ' ial and follow -up temperature surveys. An annual report for the calendar year evaluating t performance of the disposal operation must be submitted by July 1 of each y- or. The report shall include pressures, fluid volumes (disposal and clean fluid sweep , fluid make -up, injection rates, an assessment of fracture height growth, an• a description of any anomalous injection results. During the first year of injection . monthly evaluation of injection monitoring results must be provided to the Corn sion with an emphasis on fracture height growth. Also regarding the Annual DIO re• • its for this and DIO 35 (separate email), will Hilcorp be submitting partial year reports (due by July 1) or will r- sorts be for calendar years (carrying forward the Chevron rpts)? Jim Regg AOGCC 1 • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, February 02, 2012 2:14 PM To: 'Larry Greenstein' Subject: DIO #28A Annual Report - NNA #1 'r a t- z t' Report we received from David Cole is incomplete per requirements of DIO #28A, Rule 5. I've highlighted what is missing. RULE 5: Surveillance The operator shall obtain a baseline temperature log and a baseline step rate test prior to initial injection. A subsequent temperature log must be performed 1 month after injection begins to demonstrate the receiving zone of the injected fluids. Additional temperature survey requirements will be based on the results of the initial and follow -up temperature surveys. An annual report for the calendar year evaluating the performance of the disposal operation must be submitted by July 1 of each year. The report shall include pressures, fluid volumes (disposal and clean fluid sweeps), fluid make -up, injection rates, an assessment of fracture height growth, and a description of any anomalous injection results. During the first year of injection, a monthly evaluation of injection monitoring results must be provided to the Commission with an emphasis on fracture height growth. Also regarding the Annual DIO reports for this and DIO 35 (separate email), will Hilcorp be submitting partial year reports (due by July 1) or will reports be for calendar years (carrying forward the Chevron rpts)? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 I I 1 • Chevron Erin O'Brien - Authier Union Oil Company of California 410 Reservoir Engineer 3800 Centerpoint Dr., Suite 100 Anchorage, AK 99503 Tel 907 263 7653 Fax 907 263 78484 7 Email eodm @chevron.com RECEIVED May 24, 2011 [MAY 4 2011 Mr. Tom Maunder Aika & Get Cam. Counission Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 74rIcnerirg6 Anchorage, AK 99501 Re: 2010 Annual Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Maunder r0 Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2011. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2010 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were produced water from the Happy Valley field. • No MIT was required in 2010. • The average monthly injection volume into the NNA #1, during the reporting time period, was approximately 317 barrels /month. Water is trucked every five to six weeks when approximately 400 -500 bbl water has accumulated, causing the water rate to fluctuate from 0 -800 bbl water each month. • The average injection pressure was approximately 1267 psig which is below the permitted 4000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore and operating conditions. I II Union Oil Company of California / A Chevron Company http: / /www.chevron.com • • • Mr. Tom Maunder Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 The reporting time period covers one calendar year. This is consistent with Rule #5 of the AOGCC Disposal Injection Order #28A. Please contact Erin O'Brien - Authier with any questions regarding this report at 263- 7653. Sincerely, Erin O'Brien - Authier Reservoir Engineer EODM Attachment cc: Dave Whitacre Sharon Sullivan Chris Holden Larry Greenstein File Union Oil Company of California / A Chevron Company http: / /www.chevron.com NNA #1 Injection Summary -2010 1600 - _ - - 6000 1400 - - 5000 s 4, 1200 c •Q - 4000 • a i 1000 xi L N 03 a 800 3000 cc a o al ca y 600 - 2000 — a 400 0 - 1000 200 0 _ _ - 0 6: ate �' a § , �, aJ '9 , �� , ,, . P��c �e' Oo!, �o' Oe5 O P ` S —f- Tubing Press Casing Press —4—Total Monthly Inj . •. 0 • Union Oil Company of California Deep Creek Unit - NNA #1 2010 Injection Summary Total Daily Avg Monthly Days On Tubing Press Casing Press Inj Inj Cum Inj Date Max, psig Avg psig Max, psig Avg psig Bbl Bbl Bbl Dec -09 1 2610 1360 490 461 455 455 86704 Jan -10 0 1350 1267 480 480 0 0 86704 Feb -10 0 2240 1517 780 485 0 0 86704 Mar -10 1 2500 1364 480 474 655 655 87359 Apr -10 0 1475 1240 480 467 0 0 87359 May -10 1 2225 1238 480 461 690 690 88049 Jun -10 0 1110 1019 480 464 0 0 88049 Jul -10 1 3250 1270 480 457 795 795 88844 Aug -10 2 2290 1191 480 459 211.5 423 89267 Sep -10 0 2300 1455 480 448 0 0 89267 Oct -10 2 3300 1252 470 448 288 576 89843 Nov -10 0 1600 1152 480 466 0 0 89843 Dec -10 1 2300 1144 480 463 528 528 90371 • • Chevron Dave Whitacre Union Oil Company of California Technical Team Lead 3800 Centerpoint Dr., Suite 100 Cook Inlet Gas Anchorage, AK 99503 Tel 907 263 7616 Fax 907 263 78484 7 it Email whitacred @chevron.com December 2, 2010 RECEIVED DEC 9 2010 Mr. Dan Seamount Alaska Aii bas k.L16; . 4,Lcanission Alaska Oil & Gas Conservation Commission ( AOGCC) 333 West 7 Avenue, Suite 100 Anchorage Anchorage, AK 99501 Re: 2008 and 2009 Annual Disposal Reports for the NNA #1 Well in the Deep Creek Unit 5 Dear Mr. Seamount While doing an audit of our operations we discovered we were delinquent with the submittal of Annual Reports of UIC Class II disposal operations for the NNA #1 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #28A. Please note: • two calendar years of filing Disposal Reports for NNA #1 were missed (2008 and 2009). • The wells have maintained integrity and MIT's have been performed as required by Rule 3 of the AOGCC Disposal Injection Order #28A. • Only produced water from Happy Valley gas wells has been injected during 2008 and 2009. No grind and inject occurred over this time period. • Monthly injection reports (406) were submitted. We have added this annual filing into our automated system to ensure future compliance to the filing date of July 1, consistent with Rule #5 of the AOGCC Disposal Injection Order #28A. Attached please find Annual Disposal Reports for the NNA #1 Well in the Deep Creek Unit for the years 2008 and 2009. Union Oil Company of California / A Chevron Company http: / /www.chevron.com • Mr. Dan Seamount Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 Please contact Erin O'Brien - Authier with any questions at 263 -7653. Sincerely, Qv Dave Whitacre Technical Team Lead Cook Inlet Gas Team Attachments cc: Tom Maunder (AOGCC, 333 West 7 th Avenue, Suite 100, Anchorage, AK 99501) Sharon Sullivan Chris Holden Larry Greenstein Chantal Walsh File Union Oil Company of California / A Chevron Company http: / /www.chevron.com • • Chevron Erin O'Brien - Authier Union Oil Company of California Reservoir Engineer 3800 Centerpoint Dr., Suite 100 Anchorage, AK 99503 1110 Tel 907 263 7653 Fax 907 7847 Email 263 chev mil eodm�chevron.com RECEIVED DEC 0 2 2010 December 2, 2010 -4iciske psi .& G s Con. Commission Mr. Tom Maunder Anchorage Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: 2009 Annual Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Maunder moo\- ,pl5 Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2009. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2009 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were produced water from the Happy Valley Field. • The required MIT was performed and witnessed by the AOGCC on October 5, 2009 (attached). • The average monthly injection volume into the NNA #1, during the reporting time period, was approximately 722 barrels /month. A successful water shut off in HV #8 during March 2009 resulted in less disposal water during this reporting period. • The average injection pressure was approximately 1522 psig which is below the permitted 4000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore and operating conditions. The reporting time period covers one calendar year. This is consistent with Rule #5 of the AOGCC Disposal Injection Order #28A. Union Oil Company of California / A Chevron Company http: / /www.chevron.com i Iii • • Mr. Tom Maunder Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Please contact Erin O'Brien - Authier with any questions regarding this report at 263- 7653. Sincerely, kii/k Erin O'Brien - Authier Reservoir Engineer EODM Attachment cc: Dave Whitacre Sharon Sullivan Chris Holden Larry Greenstein File Union 011 Company of California / A Chevron Company http: / /www.chevron.com . , . _ NNA#1 Injection Summary-2009 2500 6000 5000 .3 to . • 4000 .0"-- • 4n 1500 3 +, w: no 0 Operational . cc E change 3000 c a. 03 a) allows Csg 73 I V 1000 al cu stabilize at c Passed MIT 2000 < —480psig Oct 5, 2009 >. c 0 500 1000 0 ----- , _ 0 411 0 e e 0 e se 0) , :f5 e (s) c).0) A •c\' N' .1' # & °Alms' Tubing Press Casing Press Total Monthly lnj • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa .aogcc.prudhoe.bay@alaska.gov OPERATOR: Union Oil Company of Califomia • FIELD 1 UNIT / PAD: Happy Valley Field / Deep Creek Unit/ NNA Pad DATE: 10/05/09 OPERATOR REP: Lou Grimaldi AOGCC REP: Steve Tanner Packer Depth Pretest Initial 15 Min. 30 Min. Well NNA #1 Type lnj. N TVD 6,131' Tubing 1,500 1,500 1,500 1,500 Interval 0 P.T.D. 2012150 Type test _ P Test psi_ 1533 Casing 520 520 520 520 P/F P Notes: Two year MIT cycle - Observed pretest conditions for OA 0 0 0 0 thirty minutes to satis 500 psi differential Well NNA #1 Type Inj. N TVD 6,131' Tubing 1,500 1,510 1,510 1,510 Interval 0 P.T.D. 2012150 Type test P Test psi 1533 Casing 520 1,690 1,680 1,675 P/F P Notes: Two year MIT cycle - Solid test OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. _ Type test_ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Driiling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water 0 = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT_NNA #1 10- 05- 09.x1s Y • • Union Oil Company of California Deep Creek Unit - NNA #1 2009 Injection Summary Daily Avg Total Monthly Days On Tubing Press Casing Press Inj Inj Cum Inj Date Max, psig Avg psig Max, psig Avg psig BbI BbI Bbl Dec -08 1 1500 1302 90 80 453 453 78033 Jan -09 4 3000 1429 130 78 336 1343 79376 Feb -09 5 2300 1612 90 78 236 1178 80554 Mar -09 2 1500 1257 85 81 319 638 81192 Apr -09 1 1900 1235 100 89 528 528 81720 May -09 4 2060 1157 90 76 204 814 82534 Jun -09 9 2800 2245 100 83 156 1400 83934 Jul-09 3 2925 1823 100 93 340 1020 84954 Aug -09 0 1850 1659 100 100 0 0 84954 Sep -09 2 3250 1749 1680 464 213 425 85379 Oct -09 1 2075 1519 500 480 405 405 85784 Nov -09 1 1300 1217 490 477 465 465 86249 Dec -09 1 2610 1360 490 461 455 455 86704 • • Chevron Erin O'Brien - Authier Union Oil Company of California Reservoir Engineer 3800 Centerpoint Dr., Suite 100 Anchorage, AK 99503 1110 Tel 907 263 7653 Fax 263 Emmail il a odm@the chevron.com RECEIVED DEC 0 2 2010 December 2, 2010 Alaska 0N alt1111431011 Mr. Tom Maunder Anchorage Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: 2008 Annual Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Maunder ` - 'rao \ — � k5 Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore for 2008. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the 2008 injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were produced water from the Happy Valley field. • No MIT was required in 2008. • The average monthly injection volume into the NNA #1, during the reporting time period, was approximately 1564 barrels /month. • The average injection pressure was approximately 1493 psig which is below the permitted 4000 psig maximum injection pressure. • Injection rates and pressures are lower than maximum allowable rates estimated to fracture through confining zones. Injection is contained within receiving intervals by confining lithologies within the Tyonek Formation, cement isolation of the wellbore and operating conditions. The reporting time period covers one calendar year. This is consistent with Rule #5 of the AOGCC Disposal Injection Order #28A. Union Oil Company of California / A Chevron Company • http: / /www_chevron.com • • Mr. Tom Maunder Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Please contact Erin O'Brien - Authier with any questions regarding this report at 263- 7653. Sincerely, 444 el7l6N,44411 Erin O'Brien - Authier Reservoir Engineer EODM Attachment cc: Dave Whitacre Sharon Sullivan Chris Holden Larry Greenstein File Union Oil Company of California / A Chevron Company http: / /www.chevron.com NNA #1 Injection Summary -2008 2500 _ __ __._ 6000 __.__. _ .. ____ _. ___.. __ -_ - 5000 2000 L 4, 0 I` 'Q - 4000 • L 1500 .o ai VI R3 VI 3000 CC 6. a o I V 1000 ,U d - 2000 c — a , a c 0 500 5 1000 0 --. _— . _.. , 0 • • ■ oc' , o`? o`� oi' o�' o` o` ,o ,o�' 0 0 , o�' Na. F�`0' fat P�� � `7 -.V �� � � �\ ,..).°0 49 000 \ ct su."- Tubing Press Casing Press Total Monthly In] • s Union Oil Company of California Deep Creek Unit - NNA #1 2008 Injection Summary Daily Avg Total Monthly Days On Tubing Press Casing Press Inj Inj Cum Inj Date Max, psig Avg psig Max, psig Avg psig Bbl Bbl Bbl Jan -08 8 3400 2030 250 139 533 4264 63530 Feb -08 4 1950 1533 150 122 444 1775 65305 Mar -08 5 3250 1798 120 92 333 1665 66970 Apr -08 3 2230 1442 135 98 371 1113 68083 May -08 2 3900 1525 130 109 1118 2235 70318 Jun -08 1 2350 1394 130 118 802 802 71120 Jul -08 1 2200 1260 135 108 1322 1322 72442 Aug -08 7 2150 1374 110 83 205 1435 73877 Sep-08 3 1620 1234 100 67 387 1160 75037 Oct -08 5 2200 1467 100 71 303 1517 76554 Nov -08 5 2200 1559 100 72 205 1026 77580 Dec -08 1 1500 1302 90 80 453 453 78033 1 Chevron Keith Lopez Union Oil Company of California Reservoir Engineer P.O. Box 196247 Anchorage, AK 99519 -6247 Tel 907 263 7653 Fax 907 263 78484 7 Email lopk @chevron.com f7:7 v • >.......w r UN 3 0 H June 27, 2008 ,IJ as:) O;i Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Annual Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Regg Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows that the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the entire injection history for the NNA #1 well bore. The change in pressure response beginning in August 07' is due to two (2) factors corresponding to the start of G &I activities. These factors are 1) a reconfiguration of the wellbore which directed injection deeper in the wellbore (within the permitted interval) and 2) an increase in injection rate due to equipment capacity. Specific items for this reporting period: • The fluids injected into the NNA #1 were: produced water from the Happy Valley field, drill cuttings and other drilling wastes from activities on the Happy Valley B Pad, and other Class II wastes covered by the injection order. • The data acquisition was modified over the history of injection (per request of the AOGCC) which is why there is no Initial 7" Casing Pressure' reported prior to March 2005. • No substantial pressure has been held on the 7" Casing since the reconfiguration of the wellbore. This is due to the installation of two packers between the 3 -1/2" injection string and the 7" casing. • The required MIT was performed and witnessing was waived by the AOGCC on September 8, 2007 (attached). Union Oil Company of California / A Chevron Company http: / /www.chevron.com Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 • The average monthly injection volume into the NNA #1, during the reporting time period, was approximately 3763 barrels. The increase in injection volume is directly related to G &I operations beginning 9/9/07. • The injection pressure is approximately 3500 psig which is below the permitted 4000 psig maximum injection pressure. This increase is directly related to the depth of the disposal zones after the reconfiguration and increased injection rates. Chevron plans to request administrative action to increase the permitted maximum surface injection pressure in 2008. The reporting time period has been adjusted from the report submitted in June 2007 to cover one calendar year. This is to be consistent with Rule #5 of the AOGCC Disposal Injection Order #28A. Please contact Keith Lopez with any questions regarding this report at 263 -7653. Sincerely, Keith Lopez Reservoir Engineer LOPK Attachment cc: Dave Whitacre Laura Hammond Jean Bodeau Larry Greenstein File Union Oil Company of California / A Chevron Company http: / /www.chevron.com . . . . • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_ Fleckenstein @admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder @admin.state.ak.us OPERATOR: Unocal Alaska FIELD / UNIT / PAD: Deep Creek Field / Happy Valley / A Pad DATE: 09/08/07 OPERATOR REP: Jason Bradford / Don Fowler AOGCC REP: Waived by Chuck Scheve on 9/7/07 @ 1830 Packer Depth Pretest Initial 15 Min. 30 Min. Well NNA #1 Type Inj. N TVD 6,131' Tubing 0 0 0 0 Interval T P.T.D. 201 -215 Type test P Test psi 1533 Casing 0 1,700 1,700 1,700 P/F P Notes: Pre - injection MIT after WO OA 0 0 0 0 Well Type Inj. TVD Tubing Interva P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interva P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring 1 = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT NNA #1 09- 08- 07.xls 1 NNA #1 Injection Summary December 2004 thru May 2008 - 4,000 — -- 7.0 Reconfigured tubing to _ 3,500 inject deeper in permitted Pumped up interval & began G &I • — 6.0 annular pressure operations • t to 2,400 psig. MIT & Increased 3,000 ♦ i annular pressure ' Pis' • to 2,500 psig. ♦ ♦ — 5.0£ ja Q 2,500 ♦� • ♦ A • • cl) i• I • i A Al N ! • ♦• • • •W ■ c i 2,000 • ♦ t t ir • a Ate 14 0 d t es ♦ ♦♦ ♦ • • •N•• *44 4 i• • a2 1,500 • i • MI • — 2.0 1,000 1 — • ■uIN=M ■■■111•111 • • (IT ■ ■ l ' 1 I' 1 — 1.0 • 500 1 ■ ■ : • • ' • • •• I 1 1 0 - ••• •0".. • • • Nw _ •�• • • • � V' LO LO LO u) LO LO CO u) LO W CO LA c0 CO CO CO c0 CO W t0 cc co c0 CO t� N. ti ti N. ti ti ti ti ti n CO ao 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o u c.- a c a a) c) c) c e`a a >, c B a) a) 5 c) c.) c a 8. >, c a a, a) c) ca c A A <a ( .r a n a a n el a; °: 's .r as a — 3 G a n n a: a: 1a C ., a ' == n n 2 a: as C • Average Tubing Injection Pressure (psig) A Ave 7" Csg Pressure (psig) 9 -5/8" Csg Pressure (psig) • Initial 7" Casing Pressure Total Daily Volume Pumped (bbls) • Average Rate (bpm) Union Oil Company of California Deep Creek Unit - NNA #1 • Injection Summary ID tav�s►.�e . '''''' Aveeeti '-'' Citi ' ' 3.� ,? r te �.. , ::i , ' , a '': 'i tl�} : ^;) to <`, i } - r '1�ui8. { }r :.. bls 1/1/2007 19,506 1/2/2007 1667 1.6 1926 0 2450 414 19,920 1/3/2007 19,920 1/4/2007 19,920 1/5/2007 1650 1.6 1924 0 2400 280 20,200 1/6/2007 20,200 1/7/2007 20,200 1/8/2007 20,200 1/9/2007 20,200 1/10/2007 20,200 1/11/2007 1544 1.6 2238 0 2350 64 20,264 1/12/2007 1686 1.6 1847 0 2300 480 20,744 1/13/2007 20,744 1/14/2007 20,744 1/15/2007 20,744 1/16/2007 20,744 1/17/2007 20,744 1/18/2007 20,744 1/19/2007 1690 1.6 1921 0 2325 448 21,192 1/20/2007 21,192 1/21/2007 21,192 1/22/2007 21,192 1/23/2007 21,192 1/24/2007 21,192 1/25/2007 21,192 1/26/2007 1686 1.6 0 1869 2300 440 21,632 1/27/2007 21,632 1/28/2007 21,632 1/29/2007 21,632 1/30/2007 21,632 1/31/2007 21,632 2/1/2007 21,632 2/2/2007 1687 1.6 1907 0 2325 456 22,088 2/3/2007 22,088 2/4/2007 22,088 2/5/2007 22,088 2/6/2007 22,088 2/7/2007 22,088 2/8/2007 22,088 2/9/2007 1364 0.9 1967 0 2316 376 22,464 2/10/2007 22,464 2/11/2007 22,464 2/12/2007 22,464 2/13/2007 22,464 2/14/2007 22,464 2/15/2007 22,464 2/16/2007 22,464 2/17/2007 22,464 2/18/2007 22,464 2/19/2007 1650 1.0 1675 0 2290 460 22,924 2/20/2007 22,924 2/21/2007 22,924 2/22/2007 22,924 2/23/2007 22,924 2/24/2007 22,924 2/25/2007 22,924 2/26/2007 22,924 2/27/2007 22,924 2/28/2007 22,924 3/1/2007 22,924 3/2/2007 22,924 3/3/2007 22,924 3/4/2007 22,924 1 Union Oil Company of California • Deep Creek Unit - NNA #1 Injection Summary • Ave :.,. JAB_ §c. ,. tnttial'r „yeti* ' "rota.(' 1?1 i1Rea ` Rate P lire tP t , . en •• ; :{ ,z; zPreset** 3/5/2007 22 3/6/2007 22,924 3/7/2007 22,924 3/8/2007 22,924 3/9/2007 22,924 3/10/2007 22,924 3/11/2007 22,924 3/12/2007 22,924 3/13/2007 22,924 3/14/2007 22,924 3/15/2007 22,924 3/16/2007 22,924 3/17/2007 22,924 3/18/2007 22,924 3/19/2007 22,924 3/20/2007 22,924 3/21/2007 22,924 3/22/2007 22,924 3/23/2007 22,924 3/24/2007 22,924 3/25/2007 22,924 3/26/2007 22,924 3/27/2007 22,924 3/28/2007 22,924 3/29/2007 22,924 3/30/2007 22,924 3/31/2007 22,924 4/1/2007 22,924 4/2/2007 22,924 4/3/2007 22,924 4/4/2007 22,924 4/5/2007 22,924 4/6/2007 22,924 4/7/2007 22,924 4/8/2007 22,924 4/9/2007 22,924 4/10/2007 22,924 4/11/2007 1624 2.0 2077 0 2175 475 23,399 4/12/2007 23,399 4/13/2007 23,399 4/14/2007 23,399 4/15/2007 23,399 4/16/2007 23,399 4/17/2007 1681 2.0 2001 0 2150 490 23,889 4/18/2007 23,889 4/19/2007 23,889 4/20/2007 23,889 4/21/2007 23,889 4/22/2007 23,889 4/23/2007 1622 1.6 1638 0 2150 408 24,297 4/24/2007 24,297 4/25/2007 24,297 4/26/2007 24,297 4/27/2007 24,297 4/28/2007 24,297 4/29/2007 24,297 4/30/2007 1667 2.0 1802 0 2125 530 24,827 5/1/2007 24,827 5/2/2007 24,827 5/3/2007 24,827 5/4/2007 24,827 5/5/2007 1578 2.0 1863 0 2100 210 25,037 5/6/2007 25,037 2 Union Oil Company of California • Deep Creek Unit - NNA #1 III Injection Summary n ° : .'. ,,." -.,,' ' Ave ""'•,. , 8-518 ".. Da[iy,'y :‘:',',A,`: 4 Tubes 4 ;Ai ge 1 .,Gsg ;,:. :'."' . Csg`,: irlidat r . Your .Tatat i ;« :Pressure - 'l ate^e Pressure,'. Pressure ;.Casing Pumped : , Dlite :' " = ' {b im)' (per }�' . (fig) ; ..Press irs . (bbls).. (b ) 5/7/2007 25,037 5/8/2007 25,037 5/9/2007 25,037 5/10/2007 25,037 5/11/2007 1612 2.0 1728 0 2110 490 25,527 5/12/2007 25,527 5/13/2007 25,527 5/14/2007 25,527 5/15/2007 25,527 5/16/2007 25,527 5/17/2007 25,527 5/18/2007 1557 2.0 1880 0 2100 210 25,737 5/19/2007 25,737 5/20/2007 1564 2.0 1982 0 2075 70 25,807 5/21/2007 1571 2.0 2075 0 2075 70 25,877 5/22/2007 1564 2.0 1975 0 2075 70 25,947 5/23/2007 25,947 5/24/2007 25,947 5/25/2007 1639 2.0 1855 0 2075 430 26,377 5/26/2007 26,377 5/27/2007 26,377 5/28/2007 26,377 5/29/2007 26,377 5/30/2007 26,377 5/31/2007 26,377 6/1/2007 1608 2.0 1725 0 2050 450 26,827 6/2/2007 26,827 6/3/2007 26,827 6/4/2007 26,827 6/5/2007 26,827 6/6/2007 26,827 6/7/2007 26,827 6/8/2007 1599 2.0 1776 0 2050 350 27,177 6/9/2007 1508 2.0 1938 0 2000 55 27,232 6/10/2007 1582 2.0 1786 0 2000 220 27,452 6/11/2007 27,452 6/12/2007 27,452 6/13/2007 27,452 6/14/2007 27,452 6/15/2007 1675 2.0 1777 0 2050 340 27,792 6/16/2007 27,792 6/17/2007 27,792 6/18/2007 27,792 6/19/2007 27,792 6/20/2007 27,792 6/21/2007 27,792 6/22/2007 1593 2.0 1770 0 2050 380 28,172 6/23/2007 28,172 6/24/2007 28,172 6/25/2007 28,172 6/26/2007 28,172 6/27/2007 28,172 6/28/2007 28,172 6/29/2007 1671 1.6 1614 0 2000 368 28,540 6/30/2007 28,540 7/1/2007 1659 2.0 1775 0 2050 350 28,890 7/2/2007 28,890 7/3/2007 28,890 7/4/2007 28,890 7/5/2007 28,890 7/6/2007 28,890 7/7/2007 28,890 7/8/2007 28,890 3 � ���� ��� � Uni�nP�Company ofCa|�o,n� ���m oeepCeexUnh' ���� � ' ' ���� Injection Summary ���� � - � � �� � � �� ��� �� � � � �m � K� � 4 � ��� ' ���� : � oa 7/9/2007 O7 28,890 . . 7/10/2007 � 7/11/2007 7/12/2007 � 7/13/2007 1647 2.0 1750 0 2000 390 29.280 : 7/14/2007 7/15/2007 7/16/2007 7/17/2007 7/18/2007 7/19/2007 7/20/2007 u�.uBO 7/21/2007 1635 2.0 113 0 525 530 29.810 7/22/2007 o9.81O 7/23/2007 7/24/2007 7/25/2007 7/26/2007 7/27/2007 7/28/2007 7/29/2007 �9.81O 7/30/2007 7/31/2007 8/1/2007 29.810 8/2/2007 8/3/2007 8/4/2007 8/5/2007 8/6/2007 8/7/2007 8/8/2007 8/9/2007 8/10/2007 8/11/2007 2S.8�O 8/12/2007 o9.8�O 8/13/2007 1504 2.0 125 0 400 400 30.270 8/14/2007 8/15/2007 8/16/2007 8/17/2007 8/18/2007 8/19/2007 8/20/2007 8/21/2007 8/22/2007 3U.27O 8/23/2007 8/24/2007 8/25/2007 8/26/2007 8/27/2007 8/28/2007 8/29/2007 8/30/2007 8/31/2007 9/1/2007 9/2/2007 �V.o7V 9/3/2007 9/4/2007 � 9/5/2007 � 9/6/2007 9/7/2007 27O . � 9/8/2007 8/9/2007 2650 2.0 0 207 30,477 4 Union Oil Company ection of California Summary • Deep Creek Unit - NNA #1 III :., �tittl ,. } i � o y rai ,,, ..•, g:e;zg t- [ubin -] ",,, :^ . 4 , 5;. >� ' . , 2• ' Dal , '. to A v± :', ; .Initial 7" . Volu Total „§ 11t tw',;PieSS� Preseur s <`, C ng` i ` � alo i t a ��, ��t t�I J }. ..kj L'',:t: 1 Ainii#::. "` l'M:.d tIbi j3' ^ ,li,(bbis) 9/10/2007 200 5.6 0 237 30,714 9/11/2007 0 - 0 0 30,714 9/12/2007 0 - 0 0 30,714 9/13/2007 0 - 0 0 30,714 9/14/2007 1350 4.2 0 140 30,854 9/15/2007 2750 3.8 0 1050 31,904 9/16/2007 0 - 0 0 31,904 9/17/2007 0 - 0 0 31,904 9/18/2007 2900 3.2 0 1748 33,652 9/19/2007 2900 3.9 0 400 34,052 9/20/2007 2925 3.6 0 493 34,545 9/21/2007 3.7 0 505 35,050 9/22/2007 0 - 0 0 35,050 9/23/2007 2925 3.8 100 1004 36,054 9/24/2007 0 - 0 0 36,054 9/25/2007 3000 3.7 100 999 37,053 9/26/2007 3025 3.7 100 463 37,516 9/27/2007 0 - 0 0 37,516 9/28/2007 2975 3.4 75 709 38,225 9/29/2007 0 - 0 0 38,225 9/30/2007 2975 3.5 70 633 38,858 10/1/2007 2950 3.5 70 502 39,360 10/2/2007 0 - 0 0 39,360 10/3/2007 2775 3.4 100 834 40,194 10/4/2007 0 - 0 0 40,194 10/5/2007 0 - 0 0 40,194 10/6/2007 0 - 0 0 40,194 10/7/2007 0 - 0 0 40,194 10/8/2007 3000 3.0 100 1375 41,569 10/9/2007 0 - 0 0 41,569 10/10/2007 0 - 0 0 41,569 10/11/2007 2850 3.5 100 655 42,224 10/12/2007 0 - 0 0 42,224 10/13/2007 0 - 0 0 42,224 10/14/2007 2850 3.3 100 648 42,872 10/15/2007 2850 4.0 50 698 43,570 10/16/2007 0 - 0 0 43,570 10/17/2007 2900 4.3 50 680 44,250 10/18/2007 2950 4.0 100 1329 45,579 10/19/2007 2900 3.9 50 792 46,371 10/20/2007 0 - 0 0 46,371 10/21/2007 0 - 0 0 46,371 10/22/2007 3200 4.1 50 634 47,005 10/23/2007 0 - 0 0 47,005 10/24/2007 3250 4.1 75 756 47,761 10/25/2007 0 - 0 0 47,761 10/26/2007 3150 4.1 90 1127 48,888 10/27/2007 3200 3.5 50 782 49,670 10/28/2007 0 - 0 0 49,670 10/29/2007 0 - 0 0 49,670 10/30/2007 3100 3.9 60 1010 50,680 10/31/2007 0 - 0 0 50,680 11/1/2007 0 - 0 0 50,680 11/2/2007 3100 4.8 80 438 51,118 11/3/2007 0 - 0 0 51,118 11/4/2007 3100 4.0 80 480 51,598 11/5/2007 0 - 0 0 51,598 11/6/2007 3125 4.0 110 1020 52,618 11/7/2007 0 - 0 0 52,618 11/8/2007 0 - 0 0 52,618 11/9/2007 3000 4.0 100 553 53,171 11/10/2007 3000 4.0 80 684 53,855 11/11/2007 0 - 0 0 53,855 5 • Union Oil Company ection of California Summary F 411 Deep Creek Unit - NNA #1 • AY8 .. , 0' , ' ;!? 11/12/2007 3000 4.0 100 589 54,444 11/13/2007 0 - 0 0 54,444 11/14/2007 3000 4.0 100 665 55,109 11/15/2007 0 - 0 0 55,109 11/16/2007 3100 3.4 100 509 55,618 11/17/2007 0 - 0 0 55,618 11/18/2007 3100 4.0 150 522 56,140 11/19/2007 0 - 0 0 56,140 11/20/2007 0 - 0 0 56,140 11/21/2007 0 - 0 0 56,140 11/22/2007 2950 4.0 130 983 57,123 11/23/2007 0 - 0 0 57,123 11/24/2007 3100 4.0 120 696 57,819 11/25/2007 0 - 0 0 57,819 11/26/2007 3100 4.0 150 1020 58,839 11/27/2007 0 - 0 0 58,839 11/28/2007 0 - 0 0 58,839 11/29/2007 0 - 0 0 58,839 11/30/2007 0 - 0 0 58,839 12/1/2007 0 - 0 0 58,839 12/2/2007 0 - 0 0 58,839 12/3/2007 0 - 0 0 58,839 12/4/2007 0 - 0 0 58,839 12/5/2007 0 - 0 0 58,839 12/6/2007 3000 4.0 180 531 59,370 12/7/2007 3200 4.0 120 931 60,301 12/8/2007 3200 4.0 150 485 60,786 12/9/2007 0 - 0 0 60,786 12/10/2007 0 - 0 0 60,786 12/11/2007 0 - 0 0 60,786 12/12/2007 3250 4.0 150 722 61,508 12/13/2007 3350 3.8 170 679 62,187 12/14/2007 0 - 0 0 62,187 1 2/15/2007 0 - 0 0 62,187 12/16/2007 3200 3.5 140 543 62,730 12/17/2007 3200 3.5 110 579 63,309 12/18/2007 0 - 0 0 63,309 12/19/2007 0 - 0 0 63,309 12/20/2007 0 - 0 0 63,309 12/21/2007 3150 4.0 120 692 64,001 12/22/2007 0 - 0 0 64,001 12/23/2007 3200 4.0 120 700 64,701 12/24/2007 0 - 0 0 64,701 12/25/2007 0 - 0 0 64,701 12/26/2007 3200 4.0 140 552 65,253 12/27/2007 3200 4.0 120 711 65,964 12/28/2007 0 - 0 0 65,964 12/29/2007 0 - 0 0 65,964 12/30/2007 0 - 0 0 65,964 12/31/2007 0 - 0 0 65,964 Total For Calendar Year 46,458 I 6 • Chevron Keith Lopez Union Oil Company of California Reservoir Engineer P.O. Box 196247 Anchorage, AK 99519 -6247 Tel 907 263 7653 Fax 907 263 78484 7 Email lopk@chevron.com J UL 0 '2 2007 Alaska Oil s Cons, Commission June 27, 2007 AnctiWage Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Annual Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Regg Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows that the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the entire injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were essentially produced water from the Happy Valley field. • The data acquisition was modified over the history of injection (per request of the AOGCC) which is why there is no Initial 7" Casing Pressure' reported prior to March 2005. • The 7" casing pressure was pumped up to 2417 psig in March 2005 which explains the step rate change in pressure. • The required MIT & temperature survey was performed and witnessed by the AOGCC on October 6, 2006. During this test the 7" casing pressure was increased to 2,500 psi. This pressure was left on the annulus explaining the increase in casing pressure after that date. • The current monthly injection volume into the NNA #1 is approximately 1718 barrels. The increase in injection volume is directly related to an increase in Happy Valley field water production. This increase is largely due to increased water production from the Happy Valley #8. • A very slight increase in tubing injection pressure can be seen beginning December 06' due to increased injection volumes. Union Oil Company of California / A Chevron Company http: / /www.chevron.com • • { ' Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 • The injection pressure is approximately 1615 psig which is significantly below the permitted 4000 psig maximum injection pressure. • The consistent pressure, relatively low water volumes, and low water rates support confinement and lack of growth out of zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes of up to 4000 BPD and at 2.5 BPM of a slurry laden fluid. In contrast, the well injection rates are currently less than 344 BPD and the injection rates approximately 1.7 BPM. Please contact Dave Whitacre with any questions regarding this report at 263 -7616. Sincerely, s Z Keith Lopez Reservoir Engineer LOPK Attachment cc: Dave Whitacre Laura Hammond Jean Bodeau Larry Greenstein File Union Oil Company of California / A Chevron Company http: / /www.chevron.com 1 Pumped up MIT & Increased annular pressure NNA #1 Injection Summary annular pressure to 2,400 psig. December 2004 thru May 2007 to 2,500 psig. 3,000 __ -- _ 6.0 • • • • • 2,500 ♦ ♦ A ..,. _, ,. i. • . •� • • 5.0 4► • I:4 ► III • • • • • 1 • ♦ ♦ ♦ C7 2,000 ♦ j ♦ ♦u♦ • ♦ ♦ 4.0 a A taji -, re i • a 1,500 • • ♦� : • • 3. 03 w m • • L < 1,000 4 411 • - r 2.0; • ••• immi• • • ■■■o ■os= ■ • • • 500 • • ■ ♦ ••• 1.0 • ■ • • ••• • •••off•• ••••w •j • 0 • -- - — ,— - - - 4 1 r 1 - t) C) C L i. > C C) C) w s C) C) C - L >. C CO 0) r S V V c L L >. C) 0 0 s c �- CU = > > n n m m is ?- (0 = ' 3 = n n °) (1) to �. C = ' = • Average Tubing Injection Pressure (psig) • Ave 7" Csg Pressure (psig) 9 -5/8" Csg Pressure (psig) • Initial 7" Casing Pressure —0-Total Daily Volume Pumped (bbls) • Average Rate (bpm) • Union Oil Company of California • Deep Creek Unit - NNA #1 • Injection Summary Average i mat Tubing Ave 7" 9 -518" Daily injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbis) 12/1/2004 12/2/2004 12/3/2004 12/4/2004 12/5/2004 12/6/2004 12/7/2004 12/8/2004 12/9/2004 12/10/2004 12/11/2004 12/12/2004 12/13/2004 1663 1.5 2657 374 374 12/14/2004 374 12/15/2004 374 12/16/2004 1693 1.5 2924 I 446 820 12/17/2004 820 12/18/2004 I 820 12/19/2004 MI 820 12/20/2004 820 12/21/2004 1034 1.5 2096 329 1,149 12/22/2004 1,149 12/23/2004 1500 1.5 2500 8 1,158 12/24/2004 1580 1.5 2173 1098 2,256 12/25/2004 2,256 12/26/2004 2,256 12/27/2004 - 2,256 12/28/2004 - 2,256 12/29/2004 2,256 12/30/2004 1719 1.5 2338 1034 3,290 12/31/2004 1757 1.4 2793 1160 4,450 1/1/2005 0 4,450 1/2/2005 4,450 1/3/2005 4,450 1/4/2005 4,450 1/5/2005 1795 2.0 2326 1 0 4,450 1/6/2005 1907 0.9 2454 0 4,450 1/7/2005 4,450 1/8/2005 4,450 1/9/2005 4,450 1/10/2005 4,450 1/11/2005 4,450 1/12/2005 4,450 1/13/2005 1613 1.4 1798 0 4,450 1/14/2005 , 4,450 1/15/2005 I 4,450 1/16/2005 - 4,450 1/17/2005 1558 2.2 1775 -� 0 4,450 1/18/2005 1444 0.9 1765 0 4,450 1/19/2005 4,450 1/20/2005 1675 1.7 2475 0 4,450 1 0 Union Oil Company of California Deep Creek Unit - NNA #1 • . Injection Summary Average i otai Tubing Ave 7" 9-518" Daily Injection Average Csg Csg initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 1/21/2005 1617 1.5 [ 2000 38 4,488 1/22/2005 1500 1.0 2567 35 4,523 1/23/2005 j 4,523 1/24/2005 1377 0.9 1843 _ 73 4,596 1/25/2005 1400 0.5 1900 25 4,621 1/26/2005 1500 1.7 1900 26 4,647 1/27/2005 1542 1.6 1796 70 4,717 1/28/2005 1600 1.5 1833 44 4,761 1/29/2005 1438 1.6 1810 86 4,847 1/30/2005 1750 1.2 1800 35 4,882 1/31/2005 1633 2.0 1800 50 4,932 2/1/2005 1650 1.3 1700 55 4,987 2/2/2005 1683 1.2 1650 55 5,042 2/3/2005 1583 1.3 1683 47 5,089 2/4/2005 1600 1.0 1770 47 5,136 2/5/2005 1367 1.5 1767 48 5,184 2/6/2005 1717 1.3 1767 46 5,230 2/7/2005 1700 1.8 1715 45 5,275 2/8/2005 1595 1.2 1750 48 5,323 2/9/2005 1410 1.3 1710 69 5,392 2/10/2005 1683 1.2 1817 50 5,442 2/11/2005 1700 1.2 1838 36 5,478 2/12/2005 5,478 2/13/2005 1600 1.6 1745 48 5,526 2/14/2005 1560 1.5 1765 30 5,556 2/15/2005 1363 1.6 1753 72 5,628 2/16/2005 1700 1.2 1727 47 5,675 2/17/2005 1625 1.4 1775 36 5,711 2/18/2005 1550 1.1 1750 38 5,749 2/19/2005 1750 1.5 1825 33 5,782 2/20/2005 1500 0.6 1795 37 5,819 2/21/2005 5 2/22/2005 1700 1.0 1792 40 5,859 2/23/2005 1650 1.6 1775 24 5,883 2/24/2005 5,883 2/25/2005 1492 1.7 1594 113 5,996 2/26/2005 5,996 2/27/2005 5,996 2/28/2005 ' 1650 1.9 1663 56 6,052 3/1/2005 i 0 6,052 3/2/2005 1325 2.0 1766 1880 80 6,132 _ 3/3/2005 0 6,132 3/4/2005 1483 1.3 1633 1900 98 6,230 3/5/2005 0 6,230 3/6/2005 1650 1.8 1717 1900 62 6,292 3/7/2005 1 0 6,292 3/8/2005 1600 1.6 1717 1900 60 6,352 3/9/2005 1378 1.4 1685 1900 60 6,412 3/10/2005 1650 1.6 1668 1860 58 6,470 3/11 /2005 1497 1.1 1750 1850 117 6,587 3/12/2005 1439 1.5 1771 2000 113 6,700 2 0 Union Oil Company of California 0 Deep Creek Unit - NNA #1 Injection Summary average i oiai Tubing Ave 7" 9 -5I8 Daily injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (obis) 3/13/2005 0 6,700 3/14/2005 1583 1.6 2417 2050 55 6,755 3/15/2005 1583 1.6 2417 2600 55 6,810 3/16/2005 1475 1.5 2200 2480 100 6,910 3/17/2005 1467 1.6 2142 2480 100 7,010 3/18/2005 1480 1.8 1976 2450 221 7,231 3/19/2005 1596 1.8 1872 2350 307 7,538 3/20/2005 1622 1.9 1939 2350 194 7,732 3/21/2005 0 7,732 3/22/2005 1509 1.5 2076H 2450 147 7,879 3/23/2005 1686 1.6 2321 2500 58 7,937 3/24/2005 0 7,937 3/25/2005 1605 1.6 2364 2500 75 8,012 3/26/2005 0 8,012 3/27/2005 0 8,012 3/28/2005 1629 1.7 2425 2500 51 8,063 3/29/2005 0 8,063 3/30/2005 0 8,063 3/31/2005 1625 1.6 2407 2500 58 8,121 4/1/2005 8,121 4/2/2005 8,121 4/3/2005 1600 1.6 2446 0 2550 56 8,177 4/4/2005 I 8,177 4/5/2005 8,177 4/6/2005 1631 1.6 2426 0 2525 56 8,233 4/7/2005 1573 1.6 2432 0 2520 64 8,297 4/8/2005 1516 1.4 2363 0 2525 70 8,367 4/9/2005 8,367 4/10/2005 8,367 4/11/2005 1592 1.6 2438 0 2520 48 8,415 4/12/2005 1637 1.6 2342 0 2500 56 8,471 4/13/2005 8,471 4/14/2005 1640 1.6 2368 0 2500 56 8,527 4/15/2005 1 8,527 4/16/2005 1 8,527 1 4/17/2005 1 8,527 4/18/2005 1650 1.7 2411 0 2500 60 8,587 4/19/2005 1504 1.6 2366 0 2480 80 8,667 4/20/2005 8,667 4/21/2005 1642 1.6 2425 0 2500 45 8,712 4/22/2005 8,712 4/23/2005 8,712 4/24/2005 8,712 I 4/25/2005 1604 1.6 2297 0 2500 176 8,888 4/26/2005 8,888 4/27/2005 8,888 4/28/2005 1700 1.6 2155 0 2500 0 8,888 4/29/2005 8,888 4/30/2005 8,888 5/1/2005 1658 1.6 i 23 0 2500 96 8,984 5/2/2005 8,984 3 • Union Oil Company of California De Creek Unit - NNA #1 0 . Injection Summary N I Average iota; Tubing Ave 7" 9 »518" Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (Obis) 5/3/2005 8,984 5/4/2005 1613 1.6 2434 0 2500 64 9,048 5/5/2005 1575 1.6 2393 0 2475 160 9,208 5/6/2005 _ 9,208 5/7/2005 9,208 5/8/2005 1589 1.6 2393 0 2475 56 9,264 5/9/2005 1580 1.6 2465 0 2500 40 9,304 5/10/2005 1583 1.6 2450 0 2500 48 9,352 5/11/2005 9,352 5/12/2005 1619 1.6 2428 0 2500 64 9,416 5/13/2005 9,416 5/14/2005 9,416 5/15/2005 1663 1.6 2425 0 2500 0 9,416 5/16/2005 1611 1.6 2417 0 2475 69 9,485 5/17/2005 9,485 5/18/2005 9,485 5/19/2005 1572 1.6 2417 0 2500 0 9,485 5/20/2005 9,485 5/21/2005 9,485 5/22/2005 1563 1.6 2413 0 2500 0 9,485 5/23/2005 9,485 5/24/2005 9,485 5/25/2005 1557 1.6 2343 0 2500 160 9,645 5/26/2005 1563 1.6 2422 0 2500 64 9,709 5/27/2005 1567 1.6 2454 0 2500 48 9,757 5/28/2005 1646 1.6 2343 0 2480 112 9,869 5/29/2005 9,869 5/30/2005 1613 1.6 2413 0 2500 64 9,933 5/31/2005 9,933 6/1/2005 1622 1.6 2431 61 2500 64 9,997 6/2/2005 9,997 6/3/2005 _ 9,997 6/4/2005 9,997 6/5/2005 9,997 6/6/2005 1492 1.6 2348 0 2500 107 10,104 6/7/2005 10,104 6/8/2005 1571 1.6 2436 0 2500 56 10,160 6/9/2005 10,160 6/10/2005 1578 1.6 2436 0 2500 70 10,230 6/11/2005 10,230 6/12/2005 1600 2.0 2383 0 2500 112 10,342 6/13/2005 10,342 6/14/2005 10,342 6/15/2005 10,342 6/16/2005 _ 10,342 6/17/2005 10,342 6/18/2005 10,342 6/19/2005 10,342 6/20/2005 1611 1.6 2400 0 2500 72 10,414 6/21/2005 10,414 6/22/2005 1467 2.0 2500 OF 2500 25 10,439 4 1 0 Union Oil Company of California Deep Creek Unit - NNA #1 Injection Summary Average - iota, Tubing Ave r 9 -518" Daily - , Injection Average Csg Csg Initial r Volume Pressure Rate Pressure Pressure Casing Pumped Date (prig) (bpm) (psig) (psig) : Pressure (bbls) 6/23/2005 1417 1.7 T 2435 0 2500 87 10,526 6/24/2005 1446 1.5 2384 0 2450 76 10,602 6/25/2005 10,602 6/26/2005 10,602 6/27/2005 10,602 6/28/2005 10,602 6/29/2005 1589 1.6 2414 0 2500 72 10,674 6/30/2005 10,674 7/1/2005 1558 1.6 2438 0 2525 48 10,722 7/2/2005 T 10,722 7/3/2005 10,722 7/4/2005 1 10,722 7/5/2005 1557 1.6 2425 0 2500 56 10,778 7/6/2005 10,778 7/7/2005 1550 1.6 2440 0 2490 42 10,820 7/8/2005 10,820 7/9/2005 10,820 7/10/2005 1608 1.6 2400 0 2500 72 10,892 7/11/2005 10,892 7/12/2005 1598 1.6 2398 0 2500 96 10,988 7/13/2005 10,988 7/14/2005 1608 1.6 2375 0 2500 120 11,108 7/15/2005 11,108 7/16/2005 1571 1.6 2417 0 2500 0 11,108 7/17/2005 11,108 7/18/2005 1613 1.6 2388 0 2500 75 11,183 _ 7/19/2005 11,183 7/20/2005 1556 1.6 2409 0 2500 64 11,247 7/21/2005 • 11,247 7/22/2005 1564 1.6 2368 0 2500 112 11,359 7/23/2005 11,359 7/24/2005 11,359 7/25/2005 11,359 7/26/2005 11,359 7/27/2005 1558 1.6 2400 0 2500 72 11,431 7/28/2005 11,431 7/29/2005 1539 1.6 2429 0 2475, 56 11,487 7/30/2005 1537 1.6 , 2403 0 2475' 56 11,543 7/31/2005 11,543 8/1/2005 1411 1.4 2439 0 2475 58 11,601 8/2/2005 1367 1.3 2396 0 2400_ 40 11,641 8/3/2005 1 11,641 8/4/2005 1517 1.5 2296 0 2500 216 11,857 8/5/2005 11,857 8/6/20051 1567 1.6 2422 0 2500 68 11,925 8/7/2005 1624 1.6 2325 0 2405 62 11,987 8/8/2005 11,987 8/9/2005 1 1464 1.6 _ 2316 0 2450 92 12,079 8/10/2005' 12,079 8/11/2005 12,079 8/12/2005 1547 1.6 2319 0 2475 120 12,199 5 0 Union Oil Company of California • Deep Creek Unit - NNA #1 Injection Summary • Average iota; Tubing Ave 7" 9.518" Daily Injection Average Csg Csg initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 8/13/2005 12,199 8/14/2005 12,199 8/15/2005 1570 1.6 2287 0 2485 120 12,319 8/16/2005 12,319 8/17/2005 12,319 8/18/2005 1529 1.6 2357 0 2450 108 12,427 8/19/2005 12,427 8/20/2005 12,427 8/21/2005 15011 1.6 2290 0 2475 120 12,547 8/22/2005 12,547 j 8/23/2005 12,547 8/24/2005 12,547 8/25/2005 1606 1.6 2340 0 2500 133 12,680 8/26/2005 12,680 8/27/2005 12,680 8/28/2005 1569 1.6 2342 0 2475 104 12,784 8/29/2005 . 12,784 8/30/2005 12,784 8/31/2005 1484 1.6 2322 0 2450 116 12,900 9/1/2005 1425 1.5 2315 0 2450 134 13,034 9/2/2005 1 1 13,034 9/3/2005 13,034 9/4/2005 13,034 9/5/2005 1477 1.6 2325 0 2425 128 13,162 9/6/2005 13,162 9/7/2005 13,162 9/8/2005 1529 1.6 2352 0 2475 128 13,290 9/9/2005 1509 1.6 2328 0 2425 128 13,418 9/10/2005 1581 1.6 2367 0 2450 • 68 13,486 9/11/2005 13,486 9/12/2005 13,486 9/13/2005 1529 1.6 2391 0 2425 65 13,551 9/14/2005 1555 1.6 2356 0 2425 64 13,615 9/15/2005 13,615 9/16/2005 1518 1.6 2301 0 2425 128 13,743 9/17/2005 1611 1.6 2375 0 2475 72 13,815 9/18/2005 1611 1.6 2375 0 2475 72 13,887 9/19/2005 1594 1.6 2375 0 2475 72 13,959 9/20/2005 1551 1.6 2304 0 2350 56 14,015 9/21/2005 1490 1.6 2313 0 2350 16 14,031 9/22/2005 14,031 _ 9/23/2005 1476 1.6 2285 0 2375 120 14,151 9/24/2005 14,151 9/25/2005 14,151 9/26/2005 14,151 9/27/2005 14,151 9/28/2005 1566 1.6 2356 0, 2400 64 14,215 9/29/2005 I 14,215 I 9/30/2005 1510 1.6 2264 01 24001 1921 14,407 10/1 /2005 1 1 14,407 10/2/2005 1617 1.6 2300 01 24001 681 14,475 6 0 Union Oil Company of California Deep Creek Unit - NNA #1 0 In Summary Average i omai Tubing Ave 7" 9-618" Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (obis) 10/3/2005 1667 1.6 2250 0 2350 72 14,547 10/4/2005 1569 1.6 2363 0 2450 64 14,611 10/5/2005 14,611 10/6/2005 1594 1.6 2375 0 2475 72 14,683 10/7/2005 14,683 10/8/2005 14,683 10/9/2005 1525 1.6 2361 0 2450 128 14,811 10/10/2005 14,811 10/11/2005 14,811 10/12/2005 14,811 10/13/2005 1581 1.6 2350 0 2450 72 14,883 10/14/2005 1 14,883 10/15/2005 1594 1.6 2356 0 2450 72 14,955 10/16/2005 14,955 10/17/2005 1617 1.6 2375 0 2475 72 15,027 10/18/2005 1606 1.6 2356 0 2450 72 15,099 10/19/2005 15,099 10/20/2005 15,099 10/21/2005 15,099 10/22/2005 1581 1.6 2322 0 2450 64 15,163 10/23/2005 1584 1.8 2240 0 2350 136 15,299 10/24/2005 15,299 10/25/2005 15,299 10/26/2005 1600 1.6 2350 0 2450 72 15,371 10/27/2005 ! 15,371 10/28/2005 1611 1.6 2361 0 2450 72 15,443 10/29/2005 1583 1.6 2350 0 2450 721 15,515 10/30/2005 1569 1.6 2313 0 2400 15,579 10/31/2005 15,579 11/1/2005 15,579 11/2/2005 1590 1.6 2236 0 2300 56 15,635 11/3/2005 1631 1.6 2185 0 2350 104 15,739 11/4/2005 15,739 11/5/2005 1592 1.6 2204 0 2300 48 15,787 11/6/2005 15,787 11/7/2005 15,787 11/8/2005 1580 1.6 2243 0 2300 56 15,843 11/9/2005 15,843 11/10/2005 15,843 11/11/2005 1594 1.6 2188 0 2325 64 15,907 11/12/2005 15,907 11/13/2005 15,907 11/14/2005 15,907 11/15/2005 1606 1.6 2238 0 2350 64 15,971 11/16/2005 15,971 11/17/2005 1483 1.6 2250 0 2300 56 16,027 11/18/2005 16,027 11/19/2005 16,027 11/20/2005 1585 1.6 2250 0 2300 60 16,087 11/21/2005 16,087 11/22/2005 16,087 7 0 Union Oil Company of California Deep Creek Unit - NNA #1 i Injection Summary . - Average 1 total Tubing Ave 7" 9-518" Daily Injection Average Csg Csg Initial 7U ' Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) - (bpm) (Prig) (psig) Pressure (bbls) 11/23/2005 16,087 11/24/2005 1600 1.6 2238 0 2350 64 16,151 11/25/2005 16,151 11/26/2005 16,151 11/27/2005 16,151 11/28/2005 1594 1.6 2275 0 2375 72 16,223 11/29/2005 16,223 11/30/2005 16,223 12/1/2005 1581 1.6 2259 0 2300 64 16,287 12/2/2005 16,287 12/3/2005 16,287 12/4/2005 1571 1.6 2286 0 2300 56 16,343 12/5/2005 16,343 12/6/2005 _ 16,343 12/7/2005 16,343 12/8/2005 1613 1.6 2188 0 2275 60 16,403 12/9/2005 16,403 12/10/2005 1 16,403 12/11/2005 16,403 12/12/2005 1617 1.6 2250_ 0 2350 72 16,475 12/13/2005 16,475 12/14/2005 16,475 12/15/2005 16,475 12/16/2005 16,475 12/17/2005 16,475 12/18/2005 16,475 12/19/2005 1543 1.6 2250 _ 0 2300 56 16,531 12/20/2005 16,531 12/21/2005 1 16,531. 12/22/2005_ 16,531 12/23/2005 1611 1.6 2275 0 2375 72 16,603 12/24/2005 16,603 12/25/2005 16,603 12/26/2005 L_ 16,603 12/27/2005 1422 1.6 2264 0 2300 72 16,675 12/28/2005 16,675 12/29/2005 16,675 12/30/2005 1517 1.0 2163 0 2300 60 16,735 12/31/2005 _ 16,735 1/1/2006 16,735 1/2/2006 16,735 1/3/2006 1567 1.6 2250 0 2350 72 16,807 1/4/2006 1 16,807 1/5/2006 1 16,807 1/6/2006 16,807 1/7/2006 1606 1 1.6 2200 0 2300 68 16,875 1/8/2006 _ 16,875 1/9/2006 16,875 1/10/2006 16,875 1/11/2006 1504 1.6 2211 0 2250 561 16,931 1/12/2006 j 16,931 8 . Union Oil Company of California Deep Creek Unit - NNA #1 Injection Summary P►verage mai Tubing Ave 7" 9-818" Daily injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 1/13/2006 1546 1.6 2238 0 2300 42 16,973 1/14/2006 16,973 1/15/2006 16,973 1/16/2006 16,973 1/17/2006 1589 1.6 2228 0 2325 651 17,038 1/18/2006 i 17,038 1/19/2006 17,038 1/20/2006 17,038 1/21/2006 1588 1.6 2163 0 2250 64 17,102 1/22/2006 17,102 1/23/2006 17,102 1/24/2006 17,102 1/25/2006 1613 1.6 2238 0 2350 64 17,166 1/26/2006 17,166 1/27/2006 17,166 1/28/2006 17,166 1/29/2006 1564 1.6 2225 0 2300 56 17,222 1/30/2006 17,222 1/31/2006 17,222 2/1/2006 17,222 2/2/2006 17,222 2/3/2006 17,222 2/4/2006 17,222 2/5/2006 1 17,222 2/6/2006 , 17,222 2/7/2006 17,222 2/8/2006 17,222 2/9/2006 _ 17,222 2/10/2006 17,222 2/11/2006 17,222 2/12/2006 17,222 2/13/2006 17,222 2/14/2006 17,222 2/15/2006 17,222 2/16/2006 1600' 1.6 2263 0 2350 64 17,286 2/17/2006 j I _ 17,286 2/18/2006 17,286 2/19/2006 17,286 2/20/2006 17,286 2/21/2006 17,286 2/22/2006 17,286 2/23/2006 17,286 2/24/2006 17,286 2/25/2006 17,286 2/26/2006 17,286 2/27/2006 17,286 2/28/2006 _ 17,286 3/1/2006 17,286 3/2/20061 17,286 3/3/2006 17,286 3/4/2006 1606 1.6 2163 0 2250 64 17,350 9 Union Oil Company of California Deep Creek Unit - NNA #1 • Injection Summary Average i otai Tubing Ave 7" 9-5/8" Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date {prig) (bpm) (psig) (psig) Pressure (bbls) 3/5/2006 17,350 3/6/2006 17,350 3/7/2006 17,350 3/8/2006 17,350 3/9/2006 17,350 3/10/2006 17,350 3/11/2006 17,350 3/12/2006 17,350 3/13/2006 17,350 3/14/2006 _ 17,350 3/15/2006 17,350 3/16/2006 17,350 3/17/2006 ( _ 17,350 3/18/2006 17,350 3/19/2006 17,350 3/20/2006 1600 1.6 2138 0 2250 64 17,414 3/21/2006 17,414 _ 3/22/2006 j 17,414 3/23/2006 17,414 3/24/2006 17,414 3/25/2006 17,414 3/26/2006 17,414 3/27/2006 17,414 3/28/2006 17,414 3/29/2006 _ 17,414 3/30/2006 17,414 3/31/2006 17,414 4/1/2006 17,414 4/2/2006 17,414 4/3/2006 17,414 4/4/2006 17,414 4/5/2006 17,414 4/6/2006 17,414 4/7/2006 17,414 4/8/2006 17,414 4/9/2006 17,414 4/10/2006 17,414 4/11/2006 17,414 4/12/2006 17,414 _ 4/13/2006 1594 1.6 2175 1 0 2275 72 17,486 4/14/2006 17,486 4/15/2006 17,486 4/16/2006 17,486 4/17/2006 17,486 4/18/2006 17,486 4/19/2006 17,486 4/20/2006 _ 17,486 4/21/2006 17,486 4/22/2006 17,486 4/23/2006 1575 1.6 _ 2192 0 2200 70 17,556 4/24/2006 C 17,556 10 0 Union Oil Company of California Deep Creek Unit - NNA #1 . Injection Summary , . , Average l i owl Tubing Ave 7" 94/8" Daily injection Average Csg Csg Initial T" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (obis) , 4/25/2006 1417 1.6 2200 0 2200 45 17,601 4/26/2006 1563 1.6 2088 0 2200 80 17,681 4/27/2006 17,681 4/28/2006 17,681 4/29/2006 17,681 4/30/2006 17,681 5/1/2006 17,681 5/2/2006 1488 1.6 2138 0 2200 32 17,713 5/3/2006 17,713 5/4/2006 17,713 5/5/2006 17,713 5/6/2006 17,713 5/7/2006 17,713 5/8/2006 17,713 5/9/2006 17,713 5/10/2006 1573 1.6 2128 0 2150 70 17,783 5/11/2006 17,783 5/12/2006 1594 1.6 2025 0 2150 68 17,851 5/13/2006 17,851 5/14/2006 17,851 5/15/2006 1513 1.6 2088 0 2175 48 17,899 5/16/2006 17,899 5/17/2006 17,899 5/18/2006 1533 1.6 2113 0 2175 48 17,947 5/19/2006 17,947 5/20/2006 17,947 5/21/2006 1509 1.6 2117 0 2200 48 17,995 5/22/2006 17,995 5/23/2006 17,995 5/24/2006 17,995 5/25/2006 17,995 5/26/2006 17,995 5/27/2006 17,995 5/28/2006 17,995 5/29/2006 17,995 5/30/2006 17,995 5/31/2006 17,995 6/1/2006 17,995 6/2/2006 17,995 6/3/2006 1551 1.6 2106 0 2200 68 18,063 6/4/2006 18,063 6/5/2006 18,063 6/6/2006 1554 1.6 2039 0 2150 56 18,119 6/7/2006 18,119 6/8/2006 18,119 6/9/2006 18,119 6/10/2006 I 18,119 6/11/2006 I 18,119 6/12/2006 1 18,119 6/13/2006 I 18,119 6/14/2006 1 18,119 11 Union Oil Company of California Deep Creek Unit - NNA #1 • Injection Summary Average 1 otai Tubing Ave 7" 9 -518" Daily injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbis) 6/15/2006 18,119 6/16/2006 18,119 6/17/2006 18,119 6/18/2006 _ 18,119 6/19/2006 18,119 6/20/2006 18,119 6/21/2006 18,119 6/22/2006 18,119 6/23/2006 18,119 6/24/2006 18,119 6/25/2006 18,119 6/26/2006 18,119 6/27/2006 1572 1.6 1975 0! 2100 66 18,185 6/28/2006 18,185 6/29/2006 18,185 6/30/2006 18,185 7/1/2006 18,185 7/2/2006 ! 18,185 7/3/2006 ! 18,185 7/4/2006 18,185 7/5/2006 18,185 7/6/2006 18,185 7/7/2006 _ 18,185 7/8/2006 18,185 7/9/2006 18,185 7/10/2006 18,185 7/11/2006 18,185 7/12/2006 18,185 7/13/2006 18,185 7/14/2006 18,185 7/15/2006 I 18,185 7/16/2006 18,185 7/17/2006 18,185 7/18/2006 18,185 7/19/2006 18,185 7/20/2006 18,185 7/21/2006 - 18,185 7/22/2006 18,185 7/23/2006 18,185 7/24/2006 18,185 7/25/2006 j J _ 18,185 7/26/2006, 1563 1.6 1988 0 2100 75 18,260 7/27/2006 18,260 7/28/2006 18,260 7/29/2006 18,260 7/30/2006 ! 18,260 7/31/2006 18,260 8/1/2006 j 18,260 8/2/2006 18,260 8/3/2006 _ 18,260 8/4/2006 18,260 12 Union Oil Company of California • Deep Creek Unit - NNA #1 • Injection Summary Average oar Tubing Ave 7" 9-5/8" Daily injection Average Csg Csg Initial7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 8/5/2006 18,260 8/6/2006 18,260 8/7/2006 18,260 8/8/2006 18,260 8/9/2006 18,260 8/10/2006 18,260 8/11/2006 18,260 8/12/2006 18,260 8/13/2006 18,260 8/14/2006 18,260 8/15/2006 18,260 8/16/2006 18,260 8/17/2006 18,260 8/18/2006 1594 1.6 1988 0 2100 64 18,324 8/19/2006 18,324 8/20/2006 18,324 8/21/2006 18,324 8/22/2006 18,324 8/23/2006 18,324 8/24/2006 18,324 8/25/2006 18,324 8/26/2006 18,324 8/27/2006 18,324 8/28/2006 18,324 8/29/2006 18,324 8/30/2006 18,324 8/31/2006 18,324 9/1/2006 18,324 9/2/2006 1575 1.6 1988 0 2100 64 18,388 9/3/2006 18,388 9/4/2006 18,388 9/5/2006 18,388 9/6/2006 18,388 9/7/2006 18,388 9/8/2006 18,388 9/9/2006 18,388 9/10/2006 18,388 9/11/2006 18,388 9/12/2006 18,388 9/13/2006 18,388 9/14/2006 18,388 9/15/2006 1575 1.6 1988 0 2100 64 18,452 9/16/2006 18,452 9/17/2006 _ 18,452 9/18/2006 18,452 9/19/2006 18,452 9/20/2006 18,452 9/21/2006 18,452 9/22/2006 18,452 9/23/2006 18,452 9/24/2006 18,452 13 0 Union Oil Company of California Deep Creek Unit - NNA #1 • . Injection Summary Average i otai Tubing Ave 7" 9-5/8" Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbis) 9/25/2006 18,452 9/26/2006 18,452 9/27/2006 18,452 9/28/2006 1563 1.6 1988 0 2100 64 18,516 9/29/2006 1 , 9/30/2006 10/1/2006 18,516 10/2/2006 18,516 10/3/2006 18,516 10/4/2006 18,516 10/5/2006 18,516 10/6/2006 1633 1.6 2266 0 2500 18,588 10/7/2006 18,588 10/8/2006 18,588 10/9/2006 18,588 10/10/2006 18,588 10/11/2006 18,588 10/12/2006 18,588 10/13/2006 18,588 10/14/2006 18,588 10/15/2006 1579 1.6 2350 0 2450 54 18,642 10/16/2006 18,642 10/17/2006 1581 1.6 2338 0 2450 64 18,706 10/18/2006 18,706 10/19/2006 18,706 10/20/2006 18,706 10/21/2006 18,706 10/22/2006 18,706 10/23/2006 I 18,706 10/24/2006 1111 18,706 10/25/2006 18,706 10/26/2006 18,706 10/27/2006 I 18,706 10/28/2006 18,706 10/29/2006 I 18,706 10/30/2006 18,706 10/31/2006 18,706 11/1/2006 18,706 11/2/2006 18,706 11/3/2006 18,706 11/4/2006 _ 18, 706 11/5/2006 18,706 11/6/2006 18,706 11/7/2006 18,706 11/8/2006 18,706 11/9/2006 18,706 11/10/2006 18,706 11/11/2006 18,706 11/12/2006 18,706 11/13/2006 18,706 11/14/2006 1 18,706 14 0 Union Oil Company of California • Deep Creek Unit - NNA #1 Injection Summary Average - ' oxai Tubing Ave 7" 9 418" Daily injection Average Csg Csg Initial 7" Volume _ Pressure Rate Pressure Pressure . Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 11/15/2006 18,706 11/16/2006 18,706 11/17/2006 18,706 11/18/2006 18,706 11/19/2006 18,706 11/20/2006 18,706 11/21/2006 18,706 11/22/2006 18,706 11/23/2006 18,706 11/24/2006 18,706 11/25/2006 18,706 11/26/2006 18,706 11/27/2006 1600 1.6 2363 0 2475 64 18,770 11/28/2006 18,770 11/29/2006 - 18,770 11/30/2006 18,770 12/1/2006 18,770 12/2/2006 _ 18,770 12/3/2006 _ 18,770 12/4/2006 _ 18,770 12/5/2006 _ 18,770 12/6/2006 18,770 12/7/2006 18,770 12/8/2006 18,770 12/9/2006 18,770 12/10/2006 18,770 12/11/2006 18,770 12/12/2006 1567 1.6 2388 0 2475 48 18,818 12/13/2006 18,818 12/14/2006 18,818 12/15/2006 _ _ 18,818 12/16/2006 18,818 12/17/2006 18,818 12/18/2006 18,818 12/19/2006 18,818 12/20/2006 1580 1.6 2350 0 2425 40 18,858 12/21/2006 _ 18,858 12/22/2006 18,858 12/23/2006 18,858 12/24/2006 1519 1.6 2231 0 2425 208 19,066 _ 12/25/2006 1606 1.6 2188 0 2300 64 19,130 12/26/2006 19,130 12/27/2006 19,130 12/28/2006 19,130 12/29/2006 1650 1.6 1875 0 2400 376 19,506 12/30/2006 19,506 12/31/2006 19,506 1/1/2007 19, 506 1/2/2007 1667 1.6 1926 0 2450 414 19,920 1/3/2007 I 19,920 1/4/2007 ! 19,920 15 0 Union Oil Company of California Deep Creek Unit - NNA #1 • . Injection Summary Average i otal Tubing Ave 1" 9 -518" Daily Injection Average Csg Csg Initial r Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 1/5/2007 1650 1.6 19241 0' 2400 280 20,200 1/6/2007 20,200 1/7/2007 20,200 1/8/2007 20,200 1/9/2007 20,200 1/10/2007 j 20,200 1/11/2007 1544 1.6 2238 0 2350 64 20,264 1/12/2007 1686 1.6 1847 0 2300 480 20,744 1/13/2007 I 20,744 1/14/2007 20,744 1/15/2007 20,744 1/16/2007 20,744 1/17/2007 1 20,744 1/18/2007 20,744 1/19/2007 1690 1.6 1921 0 2325 448 21,192 1/20/2007 21,192 1/21/2007 i 21,192 1/22/2007 fi F 21,192 1/23/2007 I 21,192 1/24/2007 21,192 1/25/2007 21,192 1/26/2007 1686 1.6 0 1869 2300 440 21,632 1/27/2007 21,632 1/28/2007 21,632 1/29/2007 _ ; 21,632 1/30/2007 1 21,632 1/31/2007 21,632 2/1/2007 21,632 2/2/2007 1687 1.6 1907; - 0 2325 456 22,088 2/3/2007 22,088 1 2/4/2007 I 22,088 2/5/2007 22,088 2/6/2007 1 22,088 2/7/2007 22,088 2/8/2007 22,088 2/9/2007 1364 0.9 1967 1 0 2316 _ 376 22,464 2/10/2007 22,464 2/11/2007 _ 22,464 2/12/2007 22,464 2/13/2007 22,464 2/14/2007 22,464 2/15/2007 22,464 2/16/2007 22,464 2/17/2007 i 22,464 2/18/2007 22,464 2/19/2007 1650 1.0 1675 0 2290 460 22,924 2/20/2007 22,924 2/21 /2007 _ 22,924 2/22/2007 22,924 2/23/2007 22,924 2/24/2007 _ 1 _ 22,924 16 Union Oil Company of California Deep Creek Unit - NNA #1 • Injection Summary Average I mar Tubing Ave 7" 9-518" Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 2/25/2007 22,924 2/26/2007 22,924 2/27/2007 22,924 2/28/2007 22,924 3/1/2007 22,924 3/2/2007 22,924 3/3/2007 _ 22,924 3/4/2007 22,924 3/5/2007 22,924 3/6/2007 22,924 3/7/2007 _ 22,924 3/8/2007 22,924 3/9/2007 22,924 3/10/2007 22,924 3/11/2007 22,924 3/12/2007 ( 22,924 3/13/2007 22,924 3/14/2007 22,924 3/15/2007 22,924 3/16/2007 _ 22,924 3/17/2007 22,924 3/18/2007 22,924 3/19/2007 22,924 3/20/2007 22,924 3/21/2007 22,924 3/22/2007 22,924 3/23/2007 - 22,924 3/24/2007 22,924 3/25/2007 1 22,924 3/26/2007 i 22,924 3/27/2007 22,924 3/28/2007 22,924 3/29/2007 22,924 3/30/2007 22,924 3/31/2007 _ 22,924 4/1/2007 22,924 4/2/2007 22,924 4/3/2007 22,924 4/4/2007 22,924 4/5/2007 22,924 4/6/2007 22,924 4/7/2007' 22,924 4/8/2007 22,924 _ 4/9/2007 22,924 4/10/2007 22,924 4/11/2007 1624 2.0 2077 0 2175 475 23,399 4/12/2007 23,399 4/13/2007 23,399 4/14/2007 23,399 4/15/2007 23,399 4/16/2007 23,399 17 0 Union Oil Company of California Deep Creek Unit - NNA #1 ` .. Injection Summary Rverage i Mal Tubing Ave 7" 9 -818" Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 4/17/2007 1681 2.0 2001 0 2150 4904 23,889 4/18/2007 23,889 4/19/2007 23,889 4/20/2007 1 23,889 4/21/2007 23,889 4/22/2007 23,889 4/23/2007 1622 1.6 1638 0 2150 408 24,297 4/24/2007 24,297 4/25/2007 1 24,297 4/26/2007 24,297 4/27/2007 24,297 4/28/2007 24,297 4/29/2007 1 24,297 4/30/2007 1667 2.0 18021 0 2125 530 24,827 5/1/2007 24,827 5/2/2007 24,827 5/3/2007 24,827 5/4/2007 24,827 5/5/2007 1578 2.0 1863 0 2100 210 25,037 5/6/2007 25,037 5/7/2007 25,037 5/8/2007 25,037 5/9/2007 1 25,037 5/10/2007 25,037 5/11/2007 1612 2.0 1728 0 2110 490 25,527 5/12/2007 25,527 5/13/2007 _ 25,527 5/14/2007 25,527 5/15/20071 25,527 5/16/2007 25,527 5/17/2007 25,527 5/18/2007 1557 2.0 1880 0 2100, 210 25,737 5/19/2007 25,737 5/20/2007 1564 2.0 1982 0 2075 70 25,807 5/21/2007 1571 2.0 2075 0 2075 70 25,877 5/22/2007 1564 2.0 1975 0 2075 70 25,947 5/23/2007 25,947 5/24/2007 25,947 5/25/2007 1639 2.0 1855 0 2075 430 26,377 5/26/2007 26,377 5/27/2007 26,377 5/28/2007 26,377 5/29/2007 26,377 5/30/2007 26,377 5/31/2007 26,377 Total 26,377 III 18 • • Chevron Ralph J. Affinito Union Oil Company of California Reservoir Engineer P.O. Box 196247 Anchorage, AK AK 99519 -6247 Tel 907 263 7847 Fax 907 263 7828 Email affinitor @chevron.com RECEN ED JUN 1 9 20 ° June 16, 2006 Al pit St Gas Cans Omission Anchorage Mr. Jim Regg 1\‘ Alaska Oil & Gas Conservation Commission (AOGCC) ('_ 333 West 7 Avenue, Suite 100 lJ Anchorage, AK 99501 Re: Annual Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Regg Attached is the Annual Report of UIC Class II disposal operations for the NNA #1 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The attached graph shows that the rates and pressures are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Note that this corresponds to the entire injection history for the NNA #1 well bore. Specific items for this reporting period: • The fluids injected into the NNA #1 were essentially produced water from the Happy Valley field. • The data acquisition was modified over the history of injection (per request of the AOGCC) which is why there is no Initial 7" Casing Pressure' reported prior to March 2005. • The 7" casing pressure was pumped up to 2417 psig in March 2005 which explains the step rate change in pressure. • The current monthly injection volume into the NNA #1 is approximately 225 barrels. The low injection volume is directly related to a decrease in the Happy Valley field water production. • The injection pressure is approximately 1600 psig which is significantly below the permitted 4000 psig injection pressure maximum. • The consistent pressure, low water volumes, and low water rates support confinement and lack of growth out of zones. Additionally, the modeling work submitted with the Application for DIO #28A showed containment with injection volumes of up to 4000 BPD and at 2.5 BPM of a slurry laden fluid. Union Oil Company of California / A Chevron Company http: / /www.chevron.com • S [Recipient Name] [Recipient Company] [Month] [Date], [Year] Page 2 In contrast, the well injection rates are currently less than 100 BPD and the injection rates approximately 1.5 BPM. Please contact Dave Whitacre with any questions regarding this report at 263 -7616. Sincerely, Ralph J. Affinito Reservoir Engineer RJA:dma Attachment cc: Dave Whitacre Laura Hammond Larry Greenstein File Union Oil Company of California / A Chevron Company http: / /www.chevron.com Pumped up . annular pressure NNA #1 Injection Summary to 2,400 psig. December 2004 thru May 2006 3,000 - ♦ - 6 i • • 2,500 • • 0311:15 •A A I A A A • • 2,000 • 1: 4 a a) _ ♦k ♦ ce a 1,500 • ♦ ♦ ♦ ♦ ♦ : ♦ �► ♦• ♦ ♦� s A 3 0 • a) �♦ ♦ ♦♦ ti a) cn a) o • 2 a 1,000 ♦■ • I a ■■ ■ 2 a me a Wiell■MIONowriiiiimii • • • Imo= et ■ 500 • ■ • 1 • • • 0 I I , - T- - I _ • .4. 10 In In In In in In In In In In CO Co CD CD CO Co o o 0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 0 0 0 a) o c as L >, c 0) 0 v v a) V C co Q a C - G a) -) 5 as Q 2 - • < < O O C 0 -, 5 < 2 - n *Average Tubing Injection Pressure (psig) •Ave 7" Csg Pressure (psig) ■ 9 -5/8" Csg Pressure (psig) • Initial 7" Casing Pressure ■Average Rate (bpm) Union Oil Company of California • Deep Creek Unit - NNA #1 • Injection Summary Average _ i otai Tubing Ave 7" 9-518' Daily 1014 n. Average Csg ° ..Csg Initial; ` "; Volume Fissure ?Rate ; pressure, = Pre sure Casing 'Pumped Date j Cpsig) Cbpm) (psig) `(prig) Pressure (bbls) 12/1/2004 12/2/2004 12/3/2004 12/4/2004 12/5/2004 12/6/2004 12/7/2004 12/8/2004 12/9/2004 12/10/2004 12/11/2004 12/12/2004 12/13/2004 1,663 1 2,657 374 12/14/2004 12/15/2004 12/16/2004 1,693 2 2,924 446 12/17/2004 12/18/2004 12/19/2004 12/20/2004 12/21/2004 1,034 2 2,096 329 12/22/2004 12/23/2004 1,500 2 2,500 8 12/24/2004 1,580 1 2,173 1,098 12/25/2004 12/26/2004 12/27/2004 12/28/2004 12/29/2004 12/30/2004 1,719 1 2,338 1,034 12/31/2004 1,757 1 2,793 1,160 1/1/2005 - 1 /2/2005 1/3/2005 1/4/2005 1/5/2005 1,795 2 2,326 - 1/6/2005 1,907 1 2,454 - 1 /7/2005 1/8/2005 1/9/2005 1/10/2005 1/11/2005 1/12/2005 1/13/2005 1,613 1 1,798 1/14/2005 1/15/2005 1/16/2005 1/17/2005 1,558 2 1,775 1/18/2005 1,444 1 1,765 1/19/2005 1/20/2005 1,675 2 2,475 - 1 Union Oil Company of California Ill Deep Creek Unit - NNA #1 111 Injection Summary „ .„ ., :.,, • ` rc i mai f Tubing : ' Ave 7"' ` �' , Dai y [S*, -, ; Initial, •. in Average Ca :` = Initial 7$ :`V+c iirii . .> E ressurii Pressure :xy Cal Pumped `,ire (1) (01 ` , ` {psig) (psig)_ :. < Pressure!- {)bis)--� 1/21/2005 1,617 1 2,000 38 1/22/2005 1,500 1 2,567 35 1/23/2005 1/24/2005 1,377 1 1,843 73 1/25/2005 1,400 1 1,900 25 1/26/2005 1,500 2 1,900 26 1/27/2005 1,542 2 1,796 70 1/28/2005 1,600 1 1,833 44 1/29/2005 1,438 2 1,810 86 1/30/2005 1,750 1 1,800 35 1/31/2005 1,633 2 1,800 50 2/1/2005 1,650 1 1,700 55 2/2/2005 1,683 1 1,650 55 2/3/2005 1,583 1 1,683 47 2/4/2005 1,600 1 1,770 47 2/5/2005 1,367 2 1,767 48 2/6/2005 1,717 1 1,767 46 2/7/2005 1,700 2 1,715 45 2/8/2005 1,595 1 1,750 48 2/9/2005 1,410 1 1,710 69 2/10/2005 1,683 1 1,817 50 2/11/2005 1,700 1 1,838 36 2/12/2005 2/13/2005 1,600 2 1,745 48 2/14/2005 1,560 2 1,765 30 2/15/2005 1,363 2 1,753 72 2/16/2005 1,700 1 1,727 47 2/17/2005 1,625 1 1,775 36 2/18/2005 1,550 1 1,750 38 2/19/2005 1,750 1 1,825 33 2/20/2005 1,500 1 1,795 37 2/21/2005 2/22/2005 1,700 1 1,792 40 2/23/2005 1,650 2 1,775 24 2/24/2005 2/25/2005 1,492 2 1,594 113 2/26/2005 2/27/2005 2/28/2005 1,650 2 1,663 56 3/1/2005 - 3/2/2005 1,325 2 1,766 1,880 80 3/3/2005 - 3/4/2005 1,483 1 1,633 1,900 98 3/5/2005 - 3/6/2005 1,650 2 1,717 1,900 62 3/7/2005 - 3/8/2005 1,600 2 1,717 1,900 60 3/9/2005 1,378 1 1,685 1,900 60 3/10/2005 1,650 2 1,668 1,860 58 3/11/2005 1,497 1 1,750 1,850 117 3/12/2005 1,439 2 1,771 2,000 113 2 Union Oil Company of California • Deep Creek Unit - NNA #1 • Injection Summary Average' ' i oai . '4' 'Cub .' ., Ave , 7� "> ' Daily ;: :�4 • t ;n -'' I ��tlon` Average . �< Cs C = #tal 7" ''Vole jay ,i� ➢ ` , P a ssure u # ; Rate - P r r( essuire: -`, Pressure - Casing -. ; rn .Pu ` \! EEa ig jjj sig ;Pressure: -, j /bb 3/13/2005 - 3/14/2005 1,583 2 2,417 2,050 55 3/15/2005 1,583 2 2,417 2,600 55 3/16/2005 1,475 2 2,200 2,480 100 3/17/2005 1,467 2 2,142 2,480 100 3/18/2005 1,480 2 1,976 2,450 221 3/19/2005 1,596 2 1,872 2,350 307 3/20/2005 1,622 2 1,939 2,350 194 3/21/2005 - 3/22/2005 1,509 1 2,076 2,450 147 3/23/2005 1,686 2 2,321 2,500 58 3/24/2005 - 3/25/2005 1,605 2 2,364 2,500 75 3/26/2005 - 3/27/2005 - 3/28/2005 1,629 2 2,425 2,500 51 3/29/2005 - 3/30/2005 - 3/31/2005 1,625 2 2,407 2,500 58 4/1/2005 4/2/2005 4/3/2005 1,600 2 2,446 - 2,550 56 4/4/2005 4/5/2005 4/6/2005 1,631 2 2,426 - 2,525 56 4/7/2005 1,573 2 2,432 - 2,520 64 4/8/2005 1,516 1 2,363 - 2,525 70 4/9/2005 4/10/2005 4/11/2005 1,592 2 2,438 - 2,520 48 4/12/2005 1,637 2 2,342 - 2,500 56 4/13/2005 4/14/2005 1,640 2 2,368 - 2,500 56 4/15/2005 4/16/2005 4/17/2005 4/18/2005 1,650 2 2,411 - 2,500 60 4/19/2005 1,504 2 2,366 - 2,480 80 4/20/2005 4/21/2005 1,642 2 2,425 - 2,500 45 4/22/2005 4/23/2005 4/24/2005 4/25/2005 1,604 2 2,297 - 2,500 176 4/26/2005 4/27/2005 4/28/2005 1,700 2 2,155 - 2,500 - 4/29/2005 4/30/2005 5/1/2005 1,658 2 2,398 - 2,500 96 5/2/2005 3 . ��mn��UCompany mYC���m� .� . III De� p<�rmekUnh'NNA#1 ���� ' �N�� |r�ection Summary ``' * ^ ' � . x��. ::? � ^ ° -��`'^~^ '~~ ' �'` .. ''~r '~ ~ -~ ' ' ' � ' .!'. '_ --` 5/3/2005 5/4/2005 1.613 2 2,434 - 2.500 64 5/5/2005 1,575 2 2.393 - 2,475 160 5/6/2005 5/7/2005 5/8/2005 1.589 2 2,393 - 2,475 56 5/9/2006 1.580 2 2,465 - 2.500 40 5/10/2005 1,583 2 2.450 - 2.600 48 5/11/2005 5/12/2005 1.619 2 2,428 - 2.500 64 5/13/2005 5/14/2005 5/15/2005 1.663 2 2,425 - 2.500 - 5/16/2005 1 2 2,417 - 2,475 69 5/17/2005 5/18/2005 5/19/2005 1,572 2 2,417 - 2.5OO - 5/20/2005 5/21/2005 5/22/2005 1 2 2,413 - 2 - 5/23/2005 5/24/2005 5/26/2005 1.557 2 2.343 - 2,500 160 5/26/2006 1.563 2 2.422 - 2.500 64 6/27/2005 1.567 2 2.454 - 2.500 48 5/28/2005 1.646 2 2,343 - 2.480 112 5/20/2006 1 5/30/2005 1.613 2 2,413 - 2.600 64 1 5/31/2005 6/1/2005 1.622 2 2,431 - 2.500 64 G/2/2UO5 6/3/2005 6/4/2005 6/5/2005 6/6/2005 1.492 2 2,348 - 2,500 107 6/7/2005 6/8/2005 1,571 2 2,436 - 2.500 56 6/9/2005 6/10/2005 1,578 2 2.436 - 2.500 70 6/11/2005 6/12/2005 1.600 2 2,383 - 2.600 112 6/13/2005 6/14/2005 6/15/2005 6/16/2005 6/17/2005 6/18/2005 6/19/2005 6/20/2005 1.611 2 2.400 - 2.500 72 6/21/2005 6/22/2005 1.467 2 2.600 - 2.600 25 4 Union Oil Company of California 0 Deep Creek Unit - NNA #1 III Injection Summary , I oui uerag� u ;1' : Tubin . .Ave r , 9 -5/8": F Dai i , _: Injection ' ,' e C '1, C Initial 7" ,Vole ,e ;:x- ::�: Wsr pure. , ,, , , , Rate , Pressure Pressure Casng § Pum bate , ' . ; : ` (prig)` 4 J (bpm) ,;(prig} "t: ' (psig) - Pressure. (bblsW r , 6/23/2005 1,417 2 2,435 - 2,500 87 6/24/2005 1,446 1 2,384 - 2,450 76 6/25/2005 6/26/2005 6/27/2005 6/28/2005 6/29/2005 1,589 2 2,414 - 2,500 72 6/30/2005 7/1/2005 1,558 2 2,438 - 2,525 48 7/2/2005 7/3/2005 7/4/2005 7/5/2005 1,557 2 2,425 - 2,500 56 7/6/2005 7/7/2005 1,550 2 2,440 - 2,490 42 7/8/2005 7/9/2005 7/10/2005 1,608 2 2,400 - 2,500 72 7/11/2005 7/12/2005 1,598 2 2,398 - 2,500 96 7/13/2005 7/14/2005 1,608 2 2,375 - 2,500 120 7/15/2005 7/16/2005 1,571 2 2,417 - 2,500 - 7/17/2005 7/18/2005 1,613 2 2,388 - 2,500 75 7/19/2005 7/20/2005 1,556 2 2,409 - 2,500 64 7/21/2005 7/22/2005 1,564 2 2,368 - 2,500 112 7/23/2005 7/24/2005 7/25/2005 7/26/2005 7/27/2005 1,558 2 2,400 - 2,500 72 7/28/2005 7/29/2005 1,539 2 2,429 - 2,475 56 7/30/2005 1,537 2 2,403 - 2,475 56 7/31/2005 8/1/2005 1,411 1 2,439 - 2,475 58 8/2/2005 1,367 1 2,396 - 2,400 40 8/3/2005 8/4/2005 1,517 1 2,296 - 2,500 216 8/5/2005 8/6/2005 1,567 2 2,422 - 2,500 68 8/7/2005 1,624 2 2,325 - 2,405 62 8/8/2005 8/9/2005 1,464 2 2,316 - 2,450 92 8/10/2005 8/11/2005 8/12/2005 1,547 2 2,319 - 2,475 120 5 Union Oil Company of California III Deep Creek Unit - NNA #1 • Injection Summary Average - ri ,F 1 01a ' Tung Ave 7" i8' ,£fir ° Ciojectiorr iAverage Csg , Csg , „ Initial 7" Volume / Pressure Rate pressure : Pressure . Casing .. Pumped Rr, � (prig) . (bpi*: ` (psig) t (pig) n Pressure " (Obis) 8/13/2005 8/14/2005 8/15/2005 1,570 2 2,287 - 2,485 120 8/16/2005 8/17/2005 8/18/2005 1,529 2 2,357 - 2,450 108 8/19/2005 8/20/2005 8/21/2005 1,501 2 2,290 - 2,475 120 8/22/2005 8/23/2005 8/24/2005 8/25/2005 1,606 2 2,340 - 2,500 133 8/26/2005 8/27/2005 8/28/2005 1,569 2 2,342 - 2,475 104 8/29/2005 8/30/2005 8/31/2005 1,484 2 2,322 - 2,450 116 9/1/2005 1,425 2 2,315 - 2,450 134 9/2/2005 9/3/2005 9/4/2005 9/5/2005 1,477 2 2,325 - 2,425 128 9/6/2005 9/7/2005 9/8/2005 1,529 2 2,352 - 2,475 128 9/9/2005 1,509 2 2,328 - 2,425 128 9/10/2005 1,581 2 2,367 - 2,450 68 9/11/2005 9/12/2005 9/13/2005 1,529 2 2,391 - 2,425 65 9/14/2005 1,555 2 2,356 - 2,425 64 9/15/2005 9/16/2005 1,518 2 2,301 - 2,425 128 9/17/2005 1,611 2 2,375 - 2,475 72 9/18/2005 1,611 2 2,375 - 2,475 72 9/19/2005 1,594 2 2,375 - 2,475 72 9/20/2005 1,551 2 2,304 - 2,350 56 9/21/2005 1,490 2 2,313 - 2,350 16 9/22/2005 9/23/2005 1,476 2 2,285 - 2,375 120 9/24/2005 9/25/2005 9/26/2005 9/27/2005 9/28/2005 1,566 2 2,356 - 2,400 64 9/29/2005 9/30/2005 1,510 2 2,264 - 2,400 192 10/1/2005 10/2/2005 1,617 2 2,300 - 2,400 68 6 Union Oil Company of California 411 Deep Creek Unit - NNA #1 ID . . Injection Summary ', ,average - r oxax Tubing k f Ave 7" 9-5/8" ; - Daily Injection Averages : Pao Cs9 : - t: initial 7 ' .. Vol • > <Pressure Rate Pressure Pressur Cas Pump ,,., (ps gi ;;: ` ' (bpm , (ps18y , (p )' Pris..t ure lbbfs ):` ; 10/3/2005 1,667 2 2,250 - 2,350 72 10/4/2005 1,569 2 2,363 - 2,450 64 10/5/2005 10/6/2005 1,594 2 2,375 - 2,475 72 10/7/2005 10/8/2005 10/9/2005 1,525 2 2,361 - 2,450 128 10/10/2005 10/11/2005 10/12/2005 10/13/2005 1,581 2 2,350 - 2,450 72 10/14/2005 10/15/2005 1,594 2 2,356 - 2,450 72 10/16/2005 10/17/2005 1,617 2 2,375 - 2,475 72 10/18/2005 1,606 2 2,356 - 2,450 72 10/19/2005 10/20/2005 10/21/2005 10/22/2005 1,581 2 2,322 - 2,450 64 10/23/2005 1,584 2 2,240 - 2,350 136 10/24/2005 10/25/2005 10/26/2005 1,600 2 2,350 - 2,450 72 10/27/2005 10/28/2005 1,611 2 2,361 - 2,450 72 10/29/2005 1,583 2 2,350 - 2,450 72 10/30/2005 1,569 2 2,313 - 2,400 64 10/31/2005 11/1/2005 11/2/2005 1,590 2 2,236 - 2,300 56 11/3/2005 1,631 2 2,185 - 2,350 104 11/4/2005 11/5/2005 1,592 2 2,204 - 2,300 48 11/6/2005 11/7/2005 11/8/2005 1,580 2 2,243 - 2,300 56 11/9/2005 11/10/2005 11/11/2005 1,594 2 2,188 - 2,325 64 11/12/2005 11/13/2005 11/14/2005 11/15/2005 1,606 2 2,238 - 2,350 64 11/16/2005 11/17/2005 1,483 2 2,250 - 2,300 56 11/18/2005 11/19/2005 11/20/2005 1,585 2 2,250 - 2,300 60 11/21/2005 11/22/2005 7 Union Deep Oil Company Creek Unit - of NNA California Injection Summary average Tubing Ave 7" 9-5/8 '� Da [j . :.": Injection Aveiegi, .. ;Csg Csg :^ " Initial ,7 > Voi�ime ; 1 pressure 4 Pressure Pressure . Casing : Pumped -g si : Pressure m , tibia i�atr� . �. >, . �" (paw " (b . �� (palm tP g }:" ; 11/23/2005 11/24/2005 1,600 2 2,238 - 2,350 64 11/25/2005 11/26/2005 11/27/2005 11/28/2005 1,594 2 2,275 - 2,375 72 11/29/2005 11/30/2005 12/1/2005 1,581 2 2,259 - 2,300 64 12/2/2005 12/3/2005 12/4/2005 1,571 2 2,286 - 2,300 56 12/5/2005 12/6/2005 12/7/2005 12/8/2005 1,613 2 2,188 - 2,275 60 12/9/2005 12/10/2005 12/11/2005 12/12/2005 1,617 2 2,250 - 2,350 72 12/13/2005 12/14/2005 12/15/2005 12/16/2005 12/17/2005 12/18/2005 12/19/2005 1,543 2 2,250 - 2,300 56 12/20/2005 12/21/2005 12/22/2005 12/23/2005 1,611 2 2,275 - 2,375 72 12/24/2005 12/25/2005 12/26/2005 12/27/2005 1,422 2 2,264 - 2,300 72 12/28/2005 12/29/2005 12/30/2005 1,517 1 2,163 - 2,300 60 12/31/2005 1/1/2006 1/2/2006 1/3/2006 1,567 2 2,250 - 2,350 72 1/4/2006 1/5/2006 1/6/2006 1/7/2006 1,606 2 2,200 - 2,300 68 1/8/2006 1/9/2006 1/10/2006 1/11/2006 1,504 2 2,211 - 2,250 56 1/12/2006 8 Union Oil Company of California Deep Creek Unit - NNA #1 Injection Summary , average oat. ' >;' `;ub Ave 7" . 9-5/8l Dai, ,etstiort Average %r' ;Cad :Csg:.: Initia ' '' y Vol e. Prs re Rate Pressure Pressure Casing `Pumper >. N 4 z [ , ..� . y tp�i�t} . a , ,t�� ° :.Cps �` wig} Pressure 1 /13/2006 1,546 2 2,238 - 2,300 42 1/14/2006 1/15/2006 1/16/2006 1/17/2006 1,589 2 2,228 - 2,325 65 1/18/2006 1/19/2006 1/20/2006 1/21/2006 1,588 2 2,163 - 2,250 64 1/22/2006 1/23/2006 1/24/2006 1/25/2006 1,613 2 2,238 - 2,350 64 1/26/2006 1/27/2006 1/28/2006 1/29/2006 1,564 2 2,225 - 2,300 56 1/30/2006 1/31/2006 2/1/2006 2/2/2006 2/3/2006 2/4/2006 2/5/2006 _ 2/6/2006 2/7/2006 2/8/2006 2/9/2006 2/10/2006 2/11/2006 2/12/2006 2/13/2006 2/14/2006 2/15/2006 2/16/2006 1,600 2 2,263 - 2,350 64 2/17/2006 2/18/2006 2/19/2006 2/20/2006 2/21/2006 2/22/2006 2/23/2006 2/24/2006 2/25/2006 2/26/2006 2/27/2006 2/28/2006 3/1/2006 3/2/2006 3/3/2006 3/4/2006 1,606 2 2,163 - 2,250 64 9 Union Oil Company of California • - Deep Creek Unit - NNA #1 Injection Summary Averag . ; _ I otat . ve 7" 9 8'� Daily > . ° in o :- vra a Csg initial 7" Velum* Cs mot � � :Ae ..:..: � .. �_ 9 , . � w urea Rate Pressure Pressure i Casing Pumped (psLg) (bPm) ..: (psigt (psig) . Pressure (bbis) ' 3/5/2006 3/6/2006 3/7/2006 3/8/2006 3/9/2006 3/10/2006 3/11/2006 3/12/2006 3/13/2006 3/14/2006 3/15/2006 3/16/2006 3/17/2006 3/18/2006 3/19/2006 3/20/2006 1,600 2 2,138 - 2,250 64 3/21/2006 3/22/2006 3/23/2006 3/24/2006 3/25/2006 3/26/2006 3/27/2006 3/28/2006 3/29/2006 3/30/2006 3/31/2006 4/1/2006 4/2/2006 4/3/2006 4/4/2006 4/5/2006 4/6/2006 4/7/2006 4/8/2006 4/9/2006 4/10/2006 4/11/2006 4/12/2006 4/13/2006 1,594 2 2,175 - 2,275 72 4/14/2006 4/15/2006 4/16/2006 4/17/2006 4/18/2006 4/19/2006 4/20/2006 4/21/2006 4/22/2006 4/23/2006 1,575 2 2,192 - 2,200 70 4/24/2006 10 Union Oil Company of California • S Deep Creek Unit - NNA #1 • Injection Summary N - Average ' i Oiaai. z Tubing Ave 7" X5/8" daily; Injection ' Average Csg Csg:: initial,7H Volume Pressure. Rate Pressure Pressure . Casmg Pumped Date (isig) (bpm) Oslo) (prig) Pressure (bbis) 4/25/2006 1,417 2 2,200 - 2,200 45 4/26/2006 1,563 2 2,088 - 2,200 80 4/27/2006 4/28/2006 4/29/2006 4/30/2006 5/1/2006 5/2/2006 1,488 2 2,138 - 2,200 32 5/3/2006 5/4/2006 5/5/2006 5/6/2006 5/7/2006 5/8/2006 5/9/2006 5/10/2006 1,573 2 2,128 - 2,150 70 5/11/2006 5/12/2006 1,594 2 2,025 - 2,150 68 5/13/2006 5/14/2006 5/15/2006 1,513 2 2,088 - 2,175 48 5/16/2006 5/17/2006 5/18/2006 1,533 2 2,113 - 2,175 48 5/19/2006 5/20/2006 5/21/2006 1,509 2 2,117 - 2,200 48 5/22/2006 5/23/2006 5/24/2006 5/25/2006 5/26/2006 5/27/2006 5/28/2006 5/29/2006 5/30/2006 5/31/2006 Total 17,995 11 1 D, Monthly Pressure Reports • f • • Chevron Ralph J. Affinito Union Oil Company of California Reservoir Engineer P.O. Box 196247 Anchorage, , AK AK 99519 -6247 Tel 907 263 7847 Fax 907 263 7828 Email affinitor @chevron.com RECEIVED FEB 1 0 2006 Alaska Oil & Gas Gans. Commission February 07, 2006 Anchorage Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Regg Attached is the January 2006 monthly update of UIC Class II disposal operations for the NNA #1 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #28A. The injection pressures and rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. This report concludes the first year of monthly monitoring. The future NNA #1 injection analyses will be submitted within the annual reports. Please contact me if I can be of further assistance at 907 - 263 -7947. Sinc ely, Ralph J. Affinito Reservoir Engineer RJA:dma Attachment cc: Laura Hammond File Union Oil Company of California / A Chevron Company http: / /www.chevron.com • • Union Oil Company of California NNA #1 Injection Summary average Tubing Ave 7" 9 -5/8" Total Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 1/1/2006 1/2/2006 1/3/2006 1567 2 2250 0 2350 72 1/4/2006 1/5/2006 1/6/2006 1/7/2006 1606 2 2200 0 2300 68 1/8/2006 1/9/2006 1/10/2006 1/11/2006 1504 2 2211 0 2250 56 1/12/2006 1/13/2006 1546 2 2238 0 2300 42 1/14/2006 1/15/2006 1/16/2006 1/17/2006 1589 2 2228 0 2325 65 1/18/2006 1/19/2006 1/20/2006 1/21/2006 1588 2 2163 0 2250 64 1/22/2006 1/23/2006 1/24/2006 1/25/2006 1613 2 2238 0 2350 64 1/26/2006 1/27/2006 1/28/2006 1/29/2006 1564 2 2225 0 2300 56 1/30/2006 1/31/2006 487 NNA #1 Injection Summary . , January - 2006 2,500 6 • • • • • • • t • • • • • • — 5 2,000 • — 4 E •N ® • • • sa a 1,500 • a) d re H C m — 3 2 0. d a> c co 1,000 R o a —2Q • • • • • • MI • 500 • — 1 0 w , c -, - 0 12/29/2005 1/3/2006 1/8/2006 1/13/2006 1/18/2006 1/23/2006 1/28/2006 2/2/2006 •Average Tubing Injection Pressure (psig) • Ave 7" Csg Pressure (psig) - 9 -5/8" Csg Pressure (psig) • Initial 7" Casing Pressure U Average Rate (bpm) • ` • • Chevron Ralph J. Affinito Union Oil Company of California Reservoir Engineer P.O. Box 196247 Anchorage, AK 99519 -6247 Tel 907 263 7947 Fax 907 263 7828 Email affinitor @chevron.com U =� October 3, 2005 .; Mr. Jim Regg 1 Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Regg: Attached are the September 2005 monthly updates of UIC Class II disposal operations for the NNA #1 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #28 issued December 7, 2004. The injection pressures and rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Please contact me if I can be of further assistance at 907- 263 -7947. Best regards, 1 M Ralph J. Affinito Attachment cc: Gary Eller Laura Hammond File Union Oil Company of California / A Chevron Company http: / /www.chevron.com NNA #1 Injection Summary Sep - 2005 3,000 _ -- ._ - -__ _ -_ ___ . _____. -___ __.___ - - - - -_ _______ _ __ . _ _ . . ___.._ ._ _._. _ 6 2,500 - - - - - -- - 4 -r -- — — -- — _ _ 5 • A • A i !• • ♦ r • t • A e • 2,000 - - - - -- - -- - 4 a N c- a> P. N c0 a 1,500 �� • • �► - - - -_._ 3 2 cp co a> ai a) > as a 1,000 - -- -- - �_ _ _- -- -- 2 > a • • • • • • • • • • • • • • • • • 500 - - - - - - - - 1 0 — — 0 8/26/2005 8/31/2005 9/5/2005 9/10/2005 9/15/2005 9/20/2005 9/25/2005 9/30/2005 10/5/2005 *Average Tubing Injection Pressure (psig) •Ave T' Csg Pressure (psig) 9 - 5/8" Csg Pressure (psig) • Initial 7" Casing Pressure •Average Rate (bpm) °'' • UNOCAL ALASKA • NNA #1 Injection Summary Average Tubing Ave 7" 9-5/8" Total Daily Injection Average Csg Csg Initial 7" ` . Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (prig) (psig) Pressure (bbls) 9/1/2005 1425 2' 2315 0 2450 134 9/2/2005 9/3/2005 1 I 9/4/20051 9/5/2005 1477 21 2325 0 24251 128 9/6/20051 1 9/7/2005 1 9/8/2005 15291 2 2352 0 2475 128 9/9/2005 1509 21 2328 0 2425 128 9/10/2005 1581 21 2367 0 24501 68 9/11/2005 1 11 9/12/2005 9/13/2005 1529 21 2391 0 24251 65 9/14/2005 15551 21 2356 0 2425 64 9/15/20051 I I I 1 9/16/2005 ( 1518 21 2301 0 2425 128 9/17/2005 1611 21 2375 0 2475 72 9/18/20051 1611 2 2375 01 24751 72 9/19/20051 1594 21 2375 01 24751 72 9/20/2005 1551 I 2 2304 0 2350 56 9/21/2005 1490 2 2313 01 2350 16 9/22/2005 9/23/20051 1476 2 2285 , 0 2375 1 120 9/24/20051 i 9/25/20051 1 1 9/26/2005 I 1 1 9/27/20051 j I 9/28/20051 15661 21 2356 01 2400 j 64 9/29/20051 I J 9/30/2005 1510 1 2 2264 0 2400, 192 Total 1,507 r • U U O CAL 'b Ralph J. Affinito Reservoir Engineer Tel 907.263.7947 Fax 907.263.7847 Cell 907.223 -6766 e -mail affinitor @chevron.com September 23, 2005 RECEIVED M SEP 2 7 2005 Mr. Jim Regg Alaska Oil & Gas Conservation Commission (PjaclQVI & Gas Cons. Commission 333 West 7 Avenue, Suite 100 Anchorage Anchorage, AK 99501 DISPOSAL REPORT FOR THE NNA #1 WELL IN THE DEEP CREEK UNIT J� Dear Mr. Regg: Attached are the July and August 2005 monthly updates of UIC Class II disposal operations for the NNA #1 welibore. These disposal operations are governed by AOGCC Disposal Injection Order #28 issued December 7, 2004. The injection pressures and rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Please contact me if I can be of further assistance at 907- 263 -7947. Sincerely, "I, Ralph J. Affinito 1 Reservoir Engineer RJA:dma Attachments cc: Laura Hammond Gary Eller File Unocal Alaska / Union Oil Company of California 909 West 9th Avenue, P. O. Box 196247, Anchorage, Alaska 99519 -6247 • UNOCAL ALASKA • NNA #1 Injection Summary Average Tubing Ave 7 9 -5/8" Total Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig r , (bpm) (psig) (psig) Pressure (bbls) 7/1/2005 1558 2 2438 0 2525 48 7/2/2005 7/3/2005 7/4/2005 7/5/2005 1557 2 2425 0 2500 56 7/6/2005 7/7/2005 1550 2 2440 0 2490 42 7/8/2005 7/9/2005 7/10/2005 1608 2 2400 0 2500 72 7/11/2005 7/12/2005 1598 2 2398 0 2500 96 7/13/2005 7/14/2005 1608 2 2375 0 2500 120 7/15/2005 7/16/2005 1571 2 2417 0 2500 0 7/17/2005 7/18/2005 1613 2 2388 0 2500 75 7/19/2005 7/20/2005 1556 2 2409 0 2500 64 7/21/2005 7/22/2005 1564 2 2368 0 2500 112 7/23/2005 7/24/2005 7/25/2005 7/26/2005 7/27/2005 1558 2 2400 0 2500 72 7/28/2005 7/29/2005 1539 2 2429 0 2475 56 7/30/2005 1537 2 2403 0 2475 56 7/31/2005 Total 869 NNA #1 Injection Summary Jul - 2005 3,000 __._____-- __----- _----- -_ -_—. __,–_ __.___._.__________- _--- _______ _�_.__._ _ 6 2,500 - • ! • • • • • • • • ! , 5 • * • • • • A • • • 2,000 - 4 a N 2 N 1,500 g • • • 0 3 0 a m a) c as m L a) cz L a 1,000 2 a • • • • • • • • • • • • • III 500 - 1 0 -- T — 0 6/27/2005 7/2/2005 7/7/2005 7/12/2005 7/17/2005 7/22/2005 7/27/2005 8/1/2005 •Average Tubing Injection Pressure (psig) •Ave 7" Csg Pressure (psig) 69 -5/8" Csg Pressure (psig) • Initial 7" Casing Pressure •Average Rate (bpm) • UNOCAL ALASKA • NNA #1 Injection Summary Average Tubing Ave 7" 9 -5/8 Total Daily Injection Average Csg Csg Initial 7 Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (pgj= (psig 4 Pressure (bbls) 8/1/2005 1411 1 2439 0 0 58 8/2/2005 1367 1 2396 0 0 40 8/3/2005 8/4/2005 1517 1 2296 0 2500 216 8/5/2005 8/6/2005 1567 2 2422 0 2500 68 8/7/2005 1624 2 2325 0 2405 62 8/8/2005 8/9/2005 1464 2 2316 0 2450 92 8/10/2005 8/11/2005 8/12/2005 1547 2 2319 0 2475 120 8/13/2005 8/14/2005 8/15/2005 1570 2 2287 0 2485 120 8/16/2005 8/17/2005 8/18/2005 1529 2 2357 0 2450 108 8/19/2005 8/20/2005 8/21/2005 1501 2 2290 0 2475 120 8/22/2005 8/23/2005 8/24/2005 8/25/2005 1606 2 2340 0 2500 133 8/26/2005 8/27/2005 8/28/2005 1569 2 2342 0 2475 104 8/29/2005 8/30/2005 8/31/2005 1484 2 2322 0 2450 116 Total 1,357 i NNA #1 Injection Summary August - 2005 3,000 6 2,500 A —A , .. �. _ 5 • • • A • a • 2,000 - 4 a N a a) 2 cc z 1,500 • • ♦ • • _ 3 a a) a) c rn — as m ai ca L < 1,000 2 , ■ • ■ • ■ • ■ • • • al • • 500 1 0 • —s — —r— 0 7/27/2005 8/1/2005 8/6/2005 8/11/2005 8/16/2005 8/21/2005 8/26/2005 8/31/2005 9/5/2005 *Average Tubing Injection Pressure (psig) •Ave 7" Csg Pressure (psig) ■9 -5/8" Csg Pressure (psig) • Initial 7" Casing Pressure •Average Rate (bpm) • • UNOCAL, Ralph J. Affinito Reservoir Engineer Tel 907.263.7947 Fax 907.263.7847 Cell 907.223 -6766 e -mail affinitor @unocal.com July 5, 2005 Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 MONTHLY DISPOSAL REPORT FOR THE NNA #1 WELL IN THE DEEP CREEK UNIT Dear Mr. Regg: Attached are the May and June 2005 monthly updates of UIC Class II disposal operations for the NNA #1 welibore. These disposal operations are governed by AOGCC Disposal Injection Order #28 issued December 7, 2004. The injection pressures and rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Please contact me if I can be of further assistance at 907- 263 -7947. Sincerely, Ralph J. Affinito Reservoir Engineer RJA:dma Attachments cc: Laura Hammond Gary Eller File Unocal Alaska / Union Oil Company of California 909 West 9th Avenue, P. O. Box 196247, Anchorage, Alaska 99519 -6247 NNA #1 Injection Summary May - 2005 3,000 ._ — 6 2,500 • • • • 1 t • • • • • •—•--j • • 5 • • A • • • • • • • • 2,000 4 N a a) cc L. w • • • • • • • • • • • • • • o X1,500 3 a a) a> c rn — co a) L a) ca < 1,000 2 a • • • • • • • • • • • • • III 500 - 1 XI �, r 0 y ® m 0- — -- • ■ • • 1 - -- 0 Iv C 4/28/2005 5/3/2005 5/8/2005 5/13/2005 5/18/2005 5/23/2005 5/28/2005 6/2/2005 rr e •Average Tubing Injection Pressure (psig) •Ave 7" Csg Pressure (psig) 9 -5/8" Csg Pressure (psig) • Initial 7" Casing Pressure ■Average Rate (bpm) 0 I . NNA #1 Injection Summary Jun - 2005 3,000 __ 6 2,500 - i A I -- - _ _- - - - - - - -A a ate- 5 A A A • Ii) 2,000 — 4 i N a. r as L c4 3 c • • C a 1,500 * 3 2 a) _ an L < 1,000 - - -- • 2 a' • • Is ■ • ■ • ■ • 500 - -- 1 33 Em 0 0 0 5/28/2005 6/2/2005 6/7/2005 6/12/2005 6/17/2005 6/22/2005 6/27/2005 7/2/2005 •Average Tubing Injection Pressure (psig) Ave • 7" Csg Pressure (psig) 9 -5/8" Csg Pressure (psig) J o c c m A Initial 7" Casing Pressure •Average Rate (bpm) z,' y o' UNOCAL ALASKA NNA #1 Injection Summary NECEIVED JUL 0 6 2005 . aska Oil & ,. coo,. C,,. yam ` ub in '* .Ave 7 518 ; ' io t a x tto $ �• / , Csg / / \ In V ol - * pare ; yl P . e Casin! limpe .., � z , ( ° .. ' (p ;� Pressure m? s} 5/1/2005 165 2 2398 0 2500 96 5/2/2005 5/3/2005 5/4/2005 1613 2 2434 0 2500 64 5/5/2005 1575 2 2393 0 2475 160 5/6/2005 5/7/2005 5/8/2005 1589 2 2393 0 2475 56 5/9/2005 1580 2 2465 0 2500 40 5/10/2005 1583 2 2450 0 2500 48 5/11/2005 5/12/2005 1619 2 2428 0 2500 64 5/13/2005 5/14/2005 5/15/2005 0 0 0 0 2500 0 5/16/2005 1611 2 2417 0 2475 69 5/17/2005 5/18/2005 5/19/2005 0 0 0 0 2500 0 5/20/2005 5/21/2005 5/22/2005 0 0 0 0 2500 0 5/23/2005 5/24/2005 5/25/2005 1557 2 2343 0 2500 160 5/26/2005 1563 2 2422 0 2500 64 5/27/2005 1567 2 2454 0 2500 48 5/28/2005 1646 2 2343 0 2480 112 5/29/2005 1 5/30/2005 1613 2 2413 0 2500 64 5/31/2005 Total 1,045 • UNOCAL ALASKA • NNA #1 Injection Summary RECEIVED JUL 0 6 2005 Alaska Oil & 6 COW. Cvs117=: I :C. %? l� nE, •/ � % � g 8l a C lad Dally "� �� ,,, C S(� ® lame s s a� 3 P sure . sx ... ' " t t " "- 6/1 /2005 1622 2 2431 0 2500 64 6/2/2005 6/3/2005 6/4/2005 6/5/2005 6/6/2005 1492 2 2348 0 2500 107 6/7/2005 6/8/2005 1571 2 2436 0 2500 56 6/9/2005 6/10/2005 1578 2 2436 0 2500 70 6/11/2005 6/12/2005 1600 2 2383 0 2500 112 6/13/2005 6/14/2005 6/15/2005 6/16/2005 6/17/2005 6/18/2005 6/19/2005 6/20/2005 1611 2 2400 0 2500 72 6/21/2005 6/22/2005 1467 2 2500 0 2500 25 6/23/2005 1417 2 2435 0 2500 87 6/24/2005 1446 1 2384 0 2450 76 6/25/2005 6/26/2005 6/27/2005 6/28/2005 6/29/2005 1589 2 2414 0 2500 72 741 Total 1. 0 0 U N O CAL 76 Ralph J. Affinito Reservoir Engineer Tel 907.263.7947 Fax 907.263.7847 Cell 907.223 -6766 e -mail affinitor @unocal.com May 2, 2005 RECEIVED MP 0 2005 Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) Alaska O:i & = =• C:;iM rtlintIliSS& 333 West 7 Avenue, Suite 100 Anc orzp,e Anchorage, AK 99501 MONTHLY DISPOSAL REPORT FOR THE NNA #1 WELL IN THE DEEP CREEK UNIT Dear Mr. Regg: Attached are the March and April 2005 monthly updates of UIC Class II disposal operations for the NNA #1 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #28 issued December 7, 2004. Note the 9%" surface casing annulus pressure reporting commenced in April and continues to read 0 psi. Also note the 7" annulus pressure was pumped up and held at the increased pressure on March 14 as indicated on the graph. Additionally, there has been no waste injection into the annulus of NNA #1 in 2005. The injection pressures and rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Please contact me if I can be of further assistance at 907- 263 -7947. Since -ly, Ralph J. Affinito Reservoir Engineer Attachment cc: Laura Hammond Gary Eller File Unocal Alaska / Union Oil Company of California 909 West 9th Avenue, P. O. Box 196247, Anchorage, Alaska 99519 -6247 • • UNOCAL ALASKA NNA #1 Injection Summary Average Ave 7" Csg Tubing Pressure Total Daily Injection Average while Initial 7" Volume Pressure Rate pumping Casing Pumped ate (psig) (bpm) (psig) Pressure (bbls) 3/1/2005 0 0 0 0 3/2/2005 1325 0 1766 1880 80 3/3/2005 0 3/4/2005 1483 1 1633 1900 98 3/5/2005 0 3/6/2005 1650 2 1717 1900 62 3/7/2005 0 3/8/2005 1600 2 1717 1900 60 3/9/2005 1378 1 1685 1900 60 3/10/2005 1650 2 1668 1860 58 3/11/2005 1497 1 1750 1850 117 3/12/2005 1439 2 1771 2000 113 3/13/2005 0 3/14/2005 1583 2 2417 2050 55 3/15/2005 1583 2 2417 2600 55 3/16/2005 1475 2 2200 2480 100 3/17/2005 1467 2 2142 2480 100 3/18/2005 1480 2 1976 2450 221 3/19/2005 1596 2 1872 2350 307 3/20/2005 1622 2 1939 2350 194 3/21/2005 0 3/22/2005 1509 1 2076 2450 147 3/23/2005 1686 2 2321 2500 58 3/24/2005 0 3/25/2005 1605 2 2364 2500 75 3/26/2005 0 3/27/2005 0 3/28/2005 1629 2 2425 2500 51 3/29/2005 0 3/30/2005 0 3/31/2005 1625 2 2407 2500 58 Total 2,069 NNA #1 Injection Summary March - 2005 3,000 _ .______--- ._ -__. _. __ ____.___ -_._. __ . ___ __..._.. 6.0 2,500 Pumped up annular 5.0 pressure to 2,500 psig. A A • A A A 2,000 • • 4.0 1 • a A • • v • • • • • • ♦ ♦ • c 1,500 • • • —•— _ • 3.0 0 a • • c CI) ♦ aa d 0 C) ai cv L a 1,000 2 .0 0 • ■1■■ a • • • ■ ■ ■ ■ ■• • ■ • ■ ■ • • 500 • 1.0 0 ■—■ 0.0 2/27/2005 3/4/2005 3/9/2005 3/14/2005 3/19/2005 3/24/2005 3/29/2005 4/3/2005 *Average Tubing Injection Pressure (psig) •Ave 7" Csg Pressure while pumping (psig) Initial 7" Csg Pressure •Average Rate (bpm) • • UNOCAL ALASKA NNA #1 Injection Summary Average Tubing Ave 7" 9 -5/8" Total Daily Injection Average Csg Csg Initial 7" Volume Pressure Rate Pressure Pressure Casing Pumped Date (psig) (bpm) (psig) (psig) Pressure (bbls) 4/1/2005 0 4/2/2005 0 4/3/2005 1600 2 2446 0 2550 56 4/4/2005 0 4/5/2005 0 4/6/2005 1631 2 2426 0 2525 56 4/7/2005 1573 2 2432 0 2520 64 4/8/2005 1516 1 2363 0 2525 70 4/9/2005 0 4/10/2005 0 4/11/2005 1592 2 2438 0 2520 48 4/12/2005 1637 2 2342 0 2500 56 4/13/2005 0 4/14/2005 1640 2 2368 0 2500 56 4/15/2005 0 4/16/2005 0 4/17/2005 0 4/18/2005 1650 2 2411 0 2500 60 4/19/2005 1504 2 2366 0 2480 80 4/20/2005 0 4/21/2005 1642 2 2425 0 2500 45 4/22/2005 0 4/23/2005 0 4/24/2005 0 4/25/2005 1604 2 2297 0 2500 176 4/26/2005 0 4/27/2005 0 4/28/2005 1700 2 2155 0 2500 0 4/29/2005 0 4/30/2005 0 Total 767 r NNA #1 Injection Summary April - 2005 5 - 5 2,500 • • • a • a • s • 4 a a • • - 4 ii3 2,000 a Q 3 2 • `° cc I:: • — d c - 2 & cu • • • ■ • • IN • • • 2 a' is - 1 • 500 - 1 0 — — — a 0 3/29/2005 4/3/2005 4/8/2005 4/13/2005 4/18/2005 4/23/2005 4/28/2005 5/3/2005 •Average Tubing Injection Pressure (psig) •Ave 7" Csg Pressure (psig) • 9 - 5/8" Csg Pressure (psig) Initial 7" Casing Pressure •Average Rate (bpm) F I III U U O CAL 7fi Ralph J. Affinito Reservoir Engineer Tel 907.263.7947 Fax 907.263.7847 Cell 907.223 -6766 e -mail affinitor @unocal.com a /--. 121 5 March 14, 2005 RECEIVEr MAR 1 5 2005 Mr. Jim Regg Alaska Oil & Gas C f.`±lrr,11rr, Alaska Oil & Gas Conservation Commission (AOGCC) Anchorage 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 MONTHLY DISPOSAL REPORT FOR THE NNA #1 WELL IN THE DEEP CREEK UNIT Dear Mr. Regg: Attached is the February 2005 monthly update of disposal operations for the NNA #1 wellbore. These disposal operations are governed by AOGCC Disposal Injection Order #28 issued December 7, 2004. The injection pressures and rates are relatively predictable and stable and do not indicate any reservoir or mechanical concerns. Please contact me if I can be of further assistance at 907- 263 -7947. Sincerely, 4 Ralph J. Affinito Reservoir Engineer RJA:dma Attachment cc: Laura Hammond File Unocal Alaska / Union Oil Company of California 909 West 9th Avenue, P. O. Box 196247, Anchorage, Alaska 99519 -6247 • UNOCAL • ALASKA NNA #1 Injection Summary ii (- `f, $ - % 'I/ Ave 1 T i ss ate +;re su 2/1/2005 1 650 1. 3 170 55 2/2/2005 1683 1.2 1650 55 2/3/2005 1583 1.3 1683 47 2/4/2005 1600 1.0 1770 47 2/5/2005 1367 1.5 1767 48 2/6/2005 1717 1.3 1767 46 2/7/2005 1700 1.8 1715 45 2/8/2005 1595 1.2 1750 48 2/9/2005 1410 1.3 1710 69 2/10/2005 1683 1.2 1817 50 2/11 /2005 1700 1.2 1838 36 2/12/2005 0 0 0 0 2/13/2005 1600 1.6 1745 48 2/14/2005 1560 1.5 1765 30 2/15/2005 1363 1.6 1753 72 2/16/2005 1700 1.2 1727 47 2/17/2005 1625 1.4 1775 36 2/18/2005 1550 1.1 1750 38 2/19/2005 1750 1.5 1825 33 2/20/2005 1500 0.6 1795 37 2/21/2005 0 0 0 0 2/22/2005 1700 1.0 1792 40 2/23/2005 1650 1.6 1775 24 2/24/2005 0 0 0 0 2/25/2005 1492 1.7 1594 113 2/26/2005 0 0 0 0 2/27/2005 0 0 0 0 2/28/2005 1650 1.9 1663 56 Total 1,120 , t NNA #1 Injection Summary Feb - 2005 2,000 - 5.0 1,800 lle:...y 4.5 r 1,600 • 4.0 • • 1,400 - - -- 3.5 _ a Q - 1,200 - -- - - -_ 3.0 °, ca e = C 1,000 2.5 L 0) 2.0 °' 43 800 - __- - ■ Es > ;, a • > 600 1 a 400 - -_ -- 1.0 • 200 - - - -- 0.5 0 0.0 2/1/2005 2/6/2005 2/11/2005 2/16/2005 2/21/2005 2/26/2005 I Average Tubing Injection Pressure (psig) —e—Ave 7" Csg Pressure (psig) (Average Rate (bpm) • (71414----ACC UNOCAL() J. Gary Eller °�•�Alaska Advising Completion Engineer Unocal Alaska Tel 907 - 263 -7848 Cell 907- 351 -1313 Fax 907- 263 -7847 E -mail: ellerg @unocal.com January 20, 2005 Mr. Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Monthly Disposal Report for the NNA #1 Well in the Deep Creek Unit Dear Mr. Regg: Class II disposal operations began in the NNA #1 well, Deep Creek Unit, on December 13, 2004. These disposal operations are governed by AOGCC Disposal Injection Order #28 issued December 7, 2004. A successful MIT was performed on December 16 after a total of 486 bbl of fluid had been pumped into the NNA #1. The MIT was witnessed by Mr. Lou Grimaldi. A follow -up temperature survey was conducted on December 31, 2004 approximately 12 hours after injecting a 1,160 bbl batch of produced fluid. The table below provides detail of the injection batches that have been disposed to date in the NNA #1 well. Table 1 - NNA #1 Disposal Periods Average Average injection Volume injection Rate Tubing Casing Perin Cate _Pumped (bbl) _._ (bpm). Pressi ,(pei . Pressure (psi) 1 12/13/04 374 1.6 1,700 2,650 2 12/16/04 836 1.6 1,750 3,100 3 12/21/04 329 1.5 1,250 2,350 4 12/23 & 12/24/04 1,106 1.4 1,700 2,200 5 12/30 & 12/31/04 1,160 1.5 1,750 2,400 6 1/5 & 1/6/05 545 2.0 1,900 2,300 7 1/13/05 606 1.5 1,700 1,850 8 1/17/05 75 0.5 1,500 1,800 Injection pressures into the NNA #1 have been very stable and predictable. The average injection pressure has been very consistent at approximately 1750 psi at 1.5 bpm. This compares with Unocal's original estimate of a 2200 psi injection pressure at 2.0 bpm. Casing pressure has fluctuated predictably due to differences in injection fluid temperature. All of the Union Oil Company of California / Unocal Alaska http: / /www.unocal.com 909 West 9th Avenue, Anchorage, Alaska 99501 Mr. Jim Regg, AOGCC III 110 January 20, 2005 Page 2 injection periods thus far have disposed of produced formation liquids and completion brines. No slurries or solids have been pumped down the tubing yet. The attached figure compares the temperature and pressure survey of December 31 with the baseline survey of October 22, 2004. Both surveys have similar character and it is apparent that most of the injection is occurring into the perforations at 6,752' — 6,772'. The fluids that were injected on December 31 were approximately 60° F, whereas the wellbore fluids had equalized with the surrounding formation temperature prior to running the baseline survey on October 22. This difference in initial fluid temperature accounts for the difference in slope of the two temperature surveys above 6,800' MD, but notice that below the primary injection interval the two curves nearly overlay. There is possibly some small injection volume occurring in the perforations at 6,200', 6,480', and 9,270', but the perforations at 6,760' dominate the temperature profile. There are no indications whatsoever that fracture height is approaching the 6,000' depth specified in DIO #28. All of the fracture modeling presented in Unocal's disposal application made the worse -case assumption that the perforations at 6,200' would be the primary disposal interval. Therefore, the fact that most of the disposal is occurring at 6,760' is very good news from a containment standpoint. With reference to the baseline survey of October 22, as you and I have previously discussed, cannot explain why temperature anomalies existed at the perforations at 6,760' and 9,270'. No injection had occurred down the tubing prior to this survey, and the general slope of the temperature survey is consistent with the natural temperature gradient in the area. The anomalies were noted on both the up and down logging passes so there is no doubt that the data is valid. Above 2,300' there does exist a change in the temperature gradient on the baseline survey. This change is due to cooling from annular disposal operations which had ceased 4 days prior to running the baseline survey. Note that the temperature survey of December 31 shows a constant slope above 6,700'. Ralph Affinito (907- 263 -7947) will likely be submitting future evaluations of the NNA #1 disposal well performance. Please contact me if I can be of further assistance. cerely, . , 1/4 \ J. , - li Eller .. Advis - • Comple ion Engineer Union Oil Company of California / Unocal Alaska http: / /www.unocal.com 909 West 9th Avenue, Anchorage, Alaska 99501 !Unocal rrNNA # 1 Fi D Creek 12 -31 -2004 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 0 Pressure- Temperature Profile 1. POOH 1000 k v 2. Overlay w/ Baseline Survey of 10 -22 -04 2000 3000 m 4000 _ \ L Y = „ w ..... _ 4 ::::, t a = ‘I1N CD 0 I. ■ 7000 8000 9000 \hi 10000 I I I I I 1 I I I 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) Pressure — Perfs Baseline Press. 10 -22 -04 Temperature Baseline Temp. 10 -22 -04 Report date: 1/10/2005 .:r 1 1 . # Well Name: NNA #1 ALASKA 'DRILLING Field: Deep Creek Unit UNOCAL 76 State: Alaska API: 50-133-20507 I I Conductor: 13 % ", 61 ppf, K -55 to AOGCC: 201 -215 71' 510' FWL & 272' FSL Sec. 11, T2S, R13W, SM Surface Casing: 9% ", 47 ppf, L -80, BTC to 2140' RT -THF: 17.88' Cmnt with 145 bbl of 12.8 ppg lead and RT -GL: 16.6' 48 bbl of 15.8 ppg tail "G" Tbg lift threads - 3 IBT Tree cxn - 2 Bowen cxn X g IXI X Perfs: T -5 6182' - 6222' (12 spf, 1/30/02) Production Tubing: 3 ", 9.2 ppf, L -80, _ = T 7 6473' 6493' (6 spf, 4/29/04) IBT -Mod with SCC to 9586' = = T -12 6752' - 6772' (6 spf, 4/29/04) _ = T -90a 9170' - 9183' (6 spf, 4/29/04) Completion T -100 9206' - 9234' (6 spf, 4/29/04) - Chemical injection sidepocket mandrel at T -105 9268' 9278' (6 spf, 4/29/04) 1953' ( ?) tki 9486' - 9526' (isolated, perf'd 1/26/02) Baker 70 40 SC 1 packer at 6097' 9607' - 9647' (isolated, perf'd 4/3/02) - Baker CMU sliding sleeve at 6151(open) 2.813" X- profile R - X- nipple at 6191' X ID= 2.813" - Baker 70 -40 SC -1 packer at 9405' - Baker CMD sliding sleeve at 9426' (closed) 2.813" X- profile XX plug installed 3/18/04, capped w/ 20' of SafeCarb 500 - Baker 85 -40 F -1 packer at 9565' , - X- nipple at 9578' Production Casino: 7 ", 29 ppf, L -80, BTC to ID= 2.813" 9926' Wireline re-entry guide at 9586' Cmnt with 172 bbl of 11.0 ppg LiteCrete lead and 66 bbl of 15.8 ppg "G" tail. Production Liner: 3 ", 9.2 ppf, L -80, ST -L Directional Data: liner from 9801' - 10578' vertical hole , , Baker ZXP packer, HMC liner hanger & tieback sleeve at 9801' PBTD = 9406' Cemented with 35 bbl of 15.8 ppg "G" TD = 10,590' Drawn by: JGE NNA -1 schematic 6 -25 -2004 June 25, 2004 1..... 4 Re: Methanol Spilled at Happy Valley Subject: Re: Methanol Spilled at Happy Valley From: Thomas Maunder <tom_maunder @admin.state.ak.us> DO' "' . v S Date: Tue, 21 Dec 2004 14:17:19 -0900 To: "Eller, Gary" <ellerg @unocal.com> CC: jim_regg @admin.state.ak.us, "Harness, Evan" <eharness @unocal.com >, "Sullivan, Faye W" <sullifw@unocal.com> Gary, Thank you for clarifying the sources of the methanol volume. The initial description of the 8 bbls as "excesss" prompted our questions. We concur that the entire methanol volume described has been used in the performance of well work associated with the production of oil /gas. From your description, none of the methanol volume under discussion would be considered new /unused. You may proceed to inject the methanol and contaminated snowmelt into your disposal well. The attention of you and your colleagues to the "detail" of asking the questions prior to proceeding with a disposal is acknowledged and appreciated. Please contact Jim or myself with any questions. Tom Maunder, PE AOGCC Eller, Gary wrote: Tom, Jim - As per our conversation, I wanted to relate to you why the methanol that was spilled at Happy Valley on 12/20/04 should be classified as exempt fluid. The methanol that was spilled had been used to test coil tubing BOPE, the HV -9 tree above the master valve, and the production flowback equipment on two separate occasions. Well HV -9 had been producing to sales for some weeks prior to us performing a frac stimulation on 12/18/04. On 12/16/04, a Veco vacuum truck was used to supply and recover methanol during the coil tubing BOP test. On 12/20/04, we used that same methanol to pressure test coil BOPE once again in HV -9. Following the second test, we tranferred most of the methanol into a tank supplied by BJ Services so that we could freeze protect coil following this second job. There was about 8 bbl remaining on the Veco vac truck that would not fit in this tank, so in order to be able to release the vac truck we had him transfer this remaining methanol into our flowback tank with the ultimate plan on disposing it in our Class II well. We did so fully confident that the fluid had met the necessary criteria for being classified as exempt. It was out of this flowback tank that the 8 bbl of 50/50 methanol spilled to the ground. I trust that this explanation is adequate. Thanks for your help in this matter, and please call me at 776 -6614 if there are any further questions. *J. Gary Eller* *Unocal Alaska* *Advising Completion Engineer* Office: 907 - 263 -7848 Cell: 907 - 351 -1313 1 of 1 12/21/2004 2:18 PM Methanol spill at Happy Valley o boo' Subject: Methanol spill at Happy Valley ,-- From: "Sullivan, Faye W" <sullifw @unocal.com> - 0 1- Date: Tue, 21 Dec 2004 10:54:23 -0900 To: tom_maunder @admin.state.ak.us CC: "Eller, Gary" <ellerg @unocal.com >, "Bailey, David S" <dbailey @unocal.com >, "Britt, Bill" <brittb @unocal.com> Tom, As we discussed, approximately 8 barrels of 50 -50 methanol and water spilled from a trailer mounted tank at Happy Valley A pad. We had used the methanol to pressure test the Coiled Tubing Unit (CTU) reel, through the tree, production lines and CTU BOPs on Happy Valley Well #9. We reclaimed the methanol in a tank (not the one that leaked) added more methanol and repeated the procedure. Once the work was completed, we placed about 8 barrels of excess 50 -50 methanol into an open topped tank. Unfortunately there was a valve under the trailer behind the rear axle which was open. Snow had accumulated in the tank and when the methanol was put into the tank, it flowed out the valve onto the herculite liner over felt and 10" timbers on the gravel pad. Apparently the snow plow had snagged part of the liner which ripped and allowed approximately two thirds of the liquid to migrate outside of the containment area. It migrated to the lined retention sump on the NW corner of the pad where it was recovered along with about 45 barrels of free liquid and an undetermined amount of snow. There is also a very small amount of gravel which was picked up in the process. I believe that this methanol and material collected in the cleanup process qualifies as a Class II fluid which can be disposed in the NNA Class II disposal well. This is to request your concurrence to dispose of this material as stated. Please advise if you agree as soon as possible. Thank you. Faye W. Sullivan Regulatory Affairs Coordinator Phone: 263-7685; Fax : 263-7698 Cell: 223 -4419 1 of 1 12/21/2004 2:17 PM +/ ry q l • UNOCAL 76 J. Gary Eller - Alaska Advising Completion Engineer Unocal Alaska Tel 907 - 263 -7848 Cell 907 - 351 -1313 Fax 907 - 263 -7847 E -mail: ellerg @unocal.com November 24, 2004 Jim Regg Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Disposal Injection Application for the NNA #1 Well in the Deep Creek Unit Dear Mr. Regg: On October 1, 2004 Unocal submitted an application to convert the NNA #1 well, Deep Creek Unit, into a UIC Class II disposal well. That application asked that a variety of exempt waste be permitted for disposal into the NNA #1. Specifically, the application requested the following: This Class 11 well will be primarily used for the injection of formation fluids (produced water, natural gas condensates, etc.) from nearby gas production wells. Unocal requests permission to dispose of approved Class 11 fluids from other Unocal operated fields as well. These fluids are completely compatible with fluids in this formation. Typical Class 11 wastes requested for injection include: drilling, completion, workover, and production fluids, glycol dehydration wastes, rig wash, drilling mud slurries, tank bottoms, NORM scale, precipitation within containment areas, and other approved Class 11 wastes. The above listed Class 11 wastes would be generated from drilling, completion, workover, and production operations. For clarification, Unocal also requests permission to dispose of exempt formation stimulation fluids, stimulation solids, and tracer materials. These materials likely can likely be categorized as completion or workover fluids, but perhaps it avoids confusion by listing them specifically. Please contact me if you have any questions. Sinc-rely, J.a Eller Advisin Completio ngineer Union Oil Company of Califomia / Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http: / /www.unocal.com 1 J b 4- UNOCAL 76 J. Gary Eller - Alaska Advising Completion Engineer Unocal Alaska Tel 907 - 263 -7848 Cell 907- 351 -1313 Fax 907 - 263 -7847 E -mail: ellerg @unocal.com November 16, 2004 Commissioner John Norman Alaska Oil & Gas Conservation Commission (AOGCC) 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Hearing of November 9, 2004 Regarding a Disposal Injection Application for the NNA #1 Well in the Deep Creek Unit Dear Mr. Norman: A hearing was held November 9, 2004 regarding Unocal's disposal injection application for the NNA #1 well in the Deep Creek Unit. During that hearing, the AOGCC requested that Unocal provide a list of notable confining layers in the NNA #1 that would help contain disposal fluids such that they cannot contaminate shallow freshwater aquifers. Unocal has below provided a list of notable shales, claystones, siltstones, and coal beds that could be expected to impede fracture growth in the NNA #1 well. • 750 - 817' MD: 67' of shale interbedded with a few thin lignitic coal seams 2 - 6' thick; • 1,090 — 1,160' MD: 70' of shale interbedded with a few thin lignitic coal seams averaging 3' thick; • 1,222 — 1,290' MD: 68' of shale and claystone with minor interbedded lignitic coal seams and siltstones; • 1,650 — 1,710' MD: 60' of shale with interbedded lignitic coal seams up to 7' thick; • 2,130 — 2,200' MD: 70' of interbedded shale and siltstone; • 2,255 — 2,310' MD: 55' of shale and interbedded lignitic coal seams of 3 - 6' thick; • 2,470 — 2,530' MD: 60' of shale and claystone; • 2,580 — 2,610' MD: 30' of lignitic coal with thin interbeds of claystone; • 2,815 — 2,865' MD: 50' of interbedded shale and siltstone; • 2,960 — 3,000' MD: 40' of interbedded lignitic coal, shale and claystone; • 3,395 — 3,555' MD: 160' of claystone and shale with interbedded siltstone and lignitic coal seams up to 6' thick; • 4,040 — 4,050' MD: 10' of lignitic coal and claystone; • 4,300 — 4,390' MD: 90' of interbedded coal, claystone and siltstone; • 4,580 — 4,760' MD: 180' of predominantly claystone interbedded with thin seams of coal, lignite and siltstone; • 5,190 — 5,260' MD: 70' of claystone with a few interbedded coal seams up to 5' thick; Union Oil Company of Califomia / Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http: / /www.unocal.com • • Commissioner John Norman, AOGCC November 16, 2004 Page 2 • 5,640 — 5,680' MD: 40' of interbedded claystone, carbonaceous shale and coal; • 5,868 — 5,877' MD: 9' of claystone and carbonaceous shale or lignite; • 5,908 — 5,918' MD: 10' of silty shale; • 5,928 — 5,983' MD: 55' of interbedded siltstone, shale, claystone and six thin coal /lignite seams between 2 - 5' thick; • 6,012 — 6,030' MD: 18' of shale and claystone with a single coal seam 3 - 4' thick; • 6,050 — 6,140' MD: 90' of claystone with minor amounts of interbedded siltstone and a 7' coal seam in the middle at 6,090' MD; • 6,233 — 6,243' MD: 10' of claystone; • 6,410 — 6,445' MD: 35' of interbedded claystone and siltstone; (End of described geologic interval; numerous other confining layers exist below 6,445' MD which are not described herein.) In addition, as requested by the AOGCC, the following confining layers have been identified which lay below the proposed injection interval. • 9,310 — 9,330' MD: 20' of tight siltstone, claystone and a single coal seam 6' thick; • 9,355 — 9,385' MD: 30' of shale and tight siltstone, with a single coal seam 8' thick; • 9,450 — 9,470' MD: 20' of claystone and shale; Please contact me if I can be of further assistance. Sinc rely, J. t Garlfflier Advising Completion Engineer Union Oil Company of Califomia / Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http: / /www.unocal.com ; • • 1 ALASKA OIL AND GAS CONSERVATION COMMISSION 2 PUBLIC HEARING 3 4 In Re: ) 5 Unocal Disposal Injection Order ) NNA #1 ) 6 ) 7 8 TRANSCRIPT OF PROCEEDINGS 9 Anchorage, Alaska November 9, 2004 10 1:00 o'clock p.m. 11 12 COMMISSIONERS: 13 • JOHN NORMAN, Chairperson 14 DAN SEAMOUNT 15 16 17 18 * * * * * 19 20 21 22 23 24 25 • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 — — - Anchorage, Alaska 99501 (907) 276 -3876 ORIGINAL • S • 1 TABLE OF CONTENTS 2 3 OPENING REMARKS BY CHAIRPERSON NORMAN Page 3 4 TESTIMONY OF MR. ELLER Page 7 5 DISCUSSION Pages 8 - 26 6 END OF PROCEEDINGS Page 26 7 8 9 * * * 10 11 12 13 • 14 15 16 17 18 19 20 21 22 23 24 25 • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 2 410 411 • 1 P R O C E E D I N G S 2 (On record) 3 CHAI• NORMAN: I'll call the hearing to order. This 4 is a hearing before the Alaska Oil and Gas Conversation 5 Commission bring held on the afternoon of Tuesday, November 6 9th, 2004. the time is approximately 1:00 o'clock p.m., and 7 the location is at the Commission's offices at 333 West 8 Seventh Aven e, Suite 100, Anchorage, Alaska. 9 I wi 1 first introduce myself. I'm John Norman, 10 Chairman of 'he Alaska Oil and Gas Conversation Commission. 11 To my left i-, Commissioner Dan Seamount. The Statute states 12 that the pre-.ence of two Commissioners constitutes a quorum, 13 so the Chair will declare that we do have a legally convened 14 meeting. 15 Present today with us is Jan Scott of Metro Court 16 Reporting. A transcript will be made of these proceedings, 17 and interest:d parties can get a copy from Metro Court 18 Reporting. 19 Noti.e of this hearing was duly published in the 20 Anchorage Daly News on October 8th, 2004. An affidavit of 21 publication 's in the file. Additionally, the file reflects 22 that the App icant gave notice as required to the surface 23 owner, Ninil.hik Native Corporation. And I will also note for 24 the record, 'hat notice of this proceeding was sent to Cook 25 Inlet Region, Inc., an owner of sub - surface in the area. And • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 3 i . • 1 likewise, notice has been sent to the State of Alaska, 2 Department of Natural Resources. 3 The hearing is today for the purpose of considering 4 the Application of Union Oil of California for a Disposal 5 Injection Order to allow underground disposal by injection of 6 Class II oil field wastes into the Unocal NNA #1 well. This 7 well is located in Section 11, Township 2, Range to South, 8 Range 13 West Seward Meridian. And Unocal, by application 9 dated October 1, and filed with the Commission on October 4, 10 as requested an order from the Commission to allow the 11 disposal by injection of Class II oil field wastes into 12 various intervals in the Tyonek formation. 13 The location, further by way of description, it's my • 14 understanding, is situated approximately six miles to the east 15 of Ninilchik, Alaska. And the depths, which will be discussed 16 further, but the approximate depth of the injection is -- it 17 looks like approximately -- measured depth about 6100 feet. 18 And I would request that Unocal, they can indicate 19 specifically the intervals into which the injection will 20 occur. 21 The application further indicates an estimate that 22 approximately 3,000 barrels a day of eligible Class II fluids 23 are proposed for injection into this well. The record does 24 not show -- the file does not reflect that there have been any 25 objections or any written comments submitted or received by • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 4 theomi i snatatbdhip oceeding . 2 T1 Tli 3 Ala -A •: inist2115n5 eafeehe 4 regul gmoaEpt.bg ario h@ommission. 5 W : i]tlaleavotasti nod #ydtpplicant . 6 Weical I bkeptithith,perS3arstifsdisigato 7 beswo ivea1srautilearsoseighigivemnsworn 8 testilony. 9 F 41 s t iradirh am t ,hers 10 persp ssmapubnalhistitione.quelat llquest Lesubmithedti4EtommisEmiclirscuss 12 thou Itli eaeen*nt erepsEbEba es . 13 I mlegmnwitd lmpgth ppli 1, 14 f ire r ommis: liffiEnneEndriAD,have 15 anpre I imthattlaitalthaveaddrethe 16 I COMMIS=FERRIMInoGEEplplied 17 fofexel pthicarlzeDnEetat er tential 18conf1cEitrEt erea #g1au1tr13 ewe�ns l9thatt i = ni4hit a ay. 20 CHABIdIRMANA.shou -1 - ollotalhag 21cloe:: isearortsjaAquinaiempeiddah,ewes 22alet•: :: d•mitabethlib_inilWlnibal 23 Counj • rh4g1r3ruOskol kbof shoudLicbc lose 24 thgzr-1 iciapilirvptectidecileprethat 25Oskol ciDifEirtan4atransabeliwthamselves 5 tYEITdD URT'RU IOrR771uG 7 . 4 ' yy�ch ,'r�lY/y 5 S • • 1 and Marathon Oil Company. 2 Additionally, I should make a disclosure that as to 3 the Deep Creek Unit, I worked in the creation of that unit 4 agreement, and at that time was representing Cook Inlet 5 Region, a land owner. 6 And so, based upon those disclosures, we will allow 7 the Applicant to make a decision as to whether you think I 8 should recuse myself. I would add that I don't know of 9 anything, based upon those prior representations, that would 10 cause me to be unable to rule impartially on this matter. 11 Commissioner Seamount, do you want to add anything? 12 COMMISSIONER SEAMOUNT: I have nothing further 13 to add, Mr. Chairman. • 14 CHAIR NORMAN: Very good. Then we will 15 proceed with testimony and would ask that you begin by first, 16 state your full name for the record and then I'll have you 17 sworn. 18 MR. ELLER: Yes, Commissioner. My name is 19 John Gary Eller. I'm an employee of Unocal Corporation. 20 CHAIR NORMAN: And would you raise your right 21 hand, please? 22 (Oath Administered) 23 MR. ELLER: I do so swear. 24 CHAIR NORMAN: Very good. You may proceed. 25 MR. ELLER: If it please the Commission, for METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 6 4 1 410 1 the purposes of this testimony, I would like to be recognized 2 as an expert witness in petroleum engineering. 3 CHAIR NORMAN: Would you state again -- the 4 Commission is certainly familiar with you, but someone reading 5 this record in the future may not, so could you give a brief 6 statement as to your educational background and experience for 7 the record, please? 8 MR. ELLER: Yes, sir. I have a Bachelor of 9 Science and Master of Science degree in Petroleum Engineering 10 from Texas A & M University. The Bachelor's degree was 11 awarded in 1985. The Master's degree was awarded in 1988, I 12 think. I've served since that time in the oil and gas 13 industry, primarily doing completion's engineering, production • 14 engineering work, done so in Louisiana, Texas and in the state 15 of Alaska for the last seven years. 16 CHAIR NORMAN: Very good. Without objection, 17 we will accept your credentials as an expert witness. Please 18 proceed. 19 TESTIMONY BY J. GARY ELLER 20 Thank you. Unocal has asked, in view of this 21 application, that in the NNA #1 well, that the specific 22 injection interval be those perforated Tyonek sands, they're 23 already perforated in the well, and measured at the depth of 24 6,182 feet to 9,278 feet. Measured depth. 25 And further, Unocal has asked for a disposal, an • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 7 • 0 • 1 allowable disposal rate of up to 3,000 barrels per day. 2 Excuse me. 3 Further, to address what the -- what both the 4 Commissioner's mentioned with regard to their history, I'm 5 confident that both Commissioner's can provide an impartial 6 assessment of the facts of this hearing and I see no need that 7 either Commissioner needs to recuse themselves. 8 Commissioners, I'm not entirely sure that I have 9 anything new to add beyond the text of the application as it 10 exists. The only work that would have any bearing on the 11 application that has taken place since then was a -- Unocal 12 ran a temperature survey as a baseline temperature survey, and 13 that was conducted on October 22nd of this year. And I intend • 14 to submit that to the Commission and it has not been done so 15 yet, the data of which. But other, I really have no new 16 information to present that's outside the application. 17 CHAIR NORMAN: Certainly, and we appreciate 18 that, that's sufficient and I do want to commend Unocal of 19 what I thought was a very good presentation. Very well done 20 and very well documented. Very thorough. The Commissioner's 21 may have some questions. 22 Let me ask you first, Mr. Seamount, do you have any 23 questions? 24 COMMISSIONER SEAMOUNT: I have a few 25 questions just for clean -up. I too, thought it was a very • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 8 • • 1 complete application, but I -- there's some clarification I 2 wanted -- or I need, and I think, you know, if you can't 3 answer the question, what give them ten days? 4 MR. ELLER: Okay. 5 CHAIR NORMAN: We'll determine that at the 6 close of the hearing. If everything is completed we won't 7 need to keep the record open, but if there are some questions, 8 we will certainly allow time. 9 MR. ELLER: Thank you. 10 COMMISSIONER SEAMOUNT: Okay. Mr. Eller, it 11 looks like this well was extensively tested, and it appears 12 you recovered some water that you got some salinities off of, 13 was there any gas at all recovered? • 14 MR. ELLER: There was no measurable gas at 15 all. There was never sufficient gas to light a flare. The 16 only gas per se that was noted was fizz gas coming out of some 17 of the water that was removed from the well bore, but nothing 18 approximating commercial gas quantity. 19 COMMISSIONER SEAMOUNT: Unfortunately. 20 MR. ELLER: That's right. 21 COMMISSIONER SEAMOUNT: Okay. On page 3 of 22 the application you mention, maximum anticipated injection 23 pressure, 4,200 psi. On page 4, the number is 4,000 psi, 24 which one is it? 25 MR. ELLER: The 4,200 psi is incorrect. • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 9 • 1 COMMISSIONER SEAMOUNT: Okay. 2 MR. ELLER: The correct number should be 4,000 3 psi, as Unocal's requested maximum injection pressure, 4 COMMISSIONER SEAMOUNT: Also, on page 4, you 5 mentioned a total of 8,000 barrels of fluid disposed in a two 6 day injection period, which represents a high side estimate. 7 Before and previous to that it stated 3,000 barrels per day, 8 is 8,000, was that just meant to be a conservative over kill? 9 MR. ELLER: It was just a simulation, yes, 10 sir. It was just -- it just happened to be ran at a 11 conservative, even higher estimate that what we were 12 requesting, yes, sir. 13 COMMISSIONER SEAMOUNT: So, we will consider • 14 3,000 as the maximum? 15 MR. ELLER: That's correct. 16 COMMISSIONER SEAMOUNT: And then below that 17 we're talking about coal intervals, am I to read that that the 18 coals are tight and they -- you think they will stop the 19 fracture or they're very untight and they'll just divert the 20 fluid into the seam? 21 MR. ELLER: No, sir, it's more of the former 22 that you mentioned, that the coals typically want the fracture 23 tip. In some circumstances the pleats of the coal can rob 24 clear fluids, yes, sir. But the nature of the various 25 properties of the coal beds, it's common though that you • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 10 • • 1 cannot open up a very wide vertical crack through them 2 readily, and so they are often are seen -- I've seen numerous 3 tracer logs for instance, that's been run in wells that were 4 fracture stimulated for production of hydro- carbons, and it's 5 often even routine that they will be blunted out against 6 significant coal beds. 7 COMMISSIONER SEAMOUNT: Okay. It seems that I 8 recall in the Green River Basin, the engineers were always 9 afraid that if there's a coal seep too close to the sand to be 10 frac, the seam would rob the sand, is that -- how is that 11 different than this? 12 MR. ELLER: What can happen, and this has 13 happened to me before in the Cook Inlet specifically, is that • 14 the -- you can open up pleats within the coal that will rob 15 fluid. 16 COMMISSIONER SEAMOUNT: Okay. 17 MR. ELLER: It will rob fluid, but when any -- 18 they're not wide enough to be able to swallow the sand grains, 19 the propent (ph) grains on a conventional frac, and that's 20 most of my experience, it would be in that. And so it's 21 common they will rob that fluid phase and you'll pack off the 22 sand right there at the -- at the coal bed, but it's because 23 of that robbing mechanism, but also because of mechanical 24 properties that tends to blunt a vertical growth through the 25 coals. • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 11 410 41/ • 1 COMMISSIONER SEAMOUNT: Okay. So, fracture 2 stimulation of coal seams in the Matanuska Valley and San Juan 3 Basin, are they designed differently than a regular sand frac? 4 MR. ELLER: I have never -- I've never 5 designed a coal bed frac, so this is not any experience of my 6 own. My understanding is that it is conducted -- the design 7 is very similar. What I don't know is whether the creation of 8 the, you know, the created frac, is it similar in geometry to 9 a -- in a sand, I just don't know that. 10 COMMISSIONER SEAMOUNT: Okay. All right. On 11 page 13 of Attachment 8, in talking about the cutting's 12 disposal evaluation by R. D. Barre, there is a figure and what 13 -- what it pertains to is on page 5 of your application, the 4110 14 statement is -- it's in the third paragraph, in this second 15 simulation, fracture does not increase substantially in 16 height, -- does increase substantially in height, but does not 17 grow past the top of the cement at 5,860 feet. And then if 18 you look at the figure or the chart on page 13, I see a depth 19 of 5,960, and I'm assuming that the colored parts -- yeah, 20 this may be something you can bring in in ten days, but I 21 assume that this colored part shows how far the fracture may 22 extend vertically and horizontally, correct? 23 MR. ELLER: That is what the figure is 24 intended to designate, yes, sir. 25 COMMISSIONER: Okay. And it looks like it • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 12 411 411 1 goes above 5,960, but I'm not sure how close it gets to 5,860. 2 MR. ELLER: Okay. Let me explain first of 3 all, what the basis of this figure was. As you've mentioned, 4 two different simulations were made, both simulations 5 contained a number of assumptions which were meant -- I'm 6 trying to search for the right word to use, -- worse case 7 assumption, if you will, in terms of the -- we've already 8 mentioned the rate at which they're pumped in excess of 3,000 9 per day. It assumed that all the injections just went into 10 strictly into the highest interval. Both simulations assumed 11 that, and 12 COMMISSIONER SEAMOUNT: Understood. 13 MR. ELLER: It's given in quite detail in the 14 application. This second simulation actually takes a non - 15 rigorous application of the coals. It looks -- it dials down, 16 if you will, the strength of the coals that we drive off the 17 log properties. In other words, it artificially weakens those 18 barriers that are commonly there to exist. We did that 19 strictly because we knew the importance of the containment was 20 referenced to the top of cement at 5,860, if I recall the 21 depth. So, you want to look at absolute worse case, under any 22 circumstances, what might we come up with, and that's what 23 this second one represents. And it certainly shows a higher 24 frac growth in the initial model, just because we did dial 25 back those containment barriers substantially. • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 13 • 1 But if I recall, and I'm going to have to check on 2 this, Commissioner, I believe that the -- that the 5,860 depth 3 would correspond just to the top of the white box, if you 4 will, that's graphically presented. So, I believe, and I 5 would have to go do some checking on this, I believe that it's 6 saying in this simulation it was within 50 foot of the top of 7 that -- at the top of cement in the -- that we noted in the 8 NNA #1 well. 9 COMMISSIONER SEAMOUNT: Okay. Do you recall 10 what -- the mud filtrate, when you drilled the NNA #1, was it 11 fresh water, or do you recall any salinities? 12 MR. ELLER: I don't recollect that, 13 Commissioner. I'm -- I recall that it was water base drilling • 14 mud, and the convention of late has been to use very high 15 selenite fluids, but I just don't recall whether that was what 16 was used NNA #1 or not. 17 COMMISSIONER SEAMOUNT: Okay. You weren't 18 there at that time, were you? 19 MR. ELLER: No, sir, I wasn't. 20 COMMISSIONER SEAMOUNT: Okay. Well, we can 21 check on that. We have the logs, right Mr. Crandall? 22 MR. CRANDALL: Yes. 23 COMMISSIONER SEAMOUNT: Okay. We can take a 24 look at that. Okay. As I said before, I think this is very 25 complete and professional application, and I have no further • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 14 III 111 • 1 questions. 2 CHAIR NORMAN: Okay. Thank you, Commissioner 3 Seamount. The application indicates that the fluids to be 4 disposed of would come from the Happy Valley area and other 5 wells, as I recall somewhere in here. What other wells? How 6 wide an area would you see drawing from? 7 MR. ELLER: Unocal has operations around the 8 entire Inlet, if you will, on the west side of the Inlet off - 9 shore and on the Kenai Peninsula, including Swanson River, the 10 Swanson River Field. The areas that would be -- that Unocal's 11 interested in, and the specific fields, if you will, that they 12 would be bringing fluids into here would include any of the 13 properties that we're drilling on the Kenai Peninsula that are 14 outside of Swanson River. 15 Unocal has disposal operations currently inside of 16 Swanson River, but permits don't allow outside fluids to be 17 brought into there. So, it would include any of those 18 operations that are going on in the Deep Creek unit or other 19 exploration work that's going on in that Ninilchik area. 20 Aside from that, I've been told that there are some 21 tank farms that we maintain on the west of -- I believe it's 22 Trading Bay, I stand to be corrected, but I think that's 23 correct, and on occasion the tanks need to be cleaned. And so 24 tank bottoms from those areas could conceivably be hauled over 25 to the NNA #1 for disposal. To my knowledge, that would be METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 15 411 411 • 1 the extent of it. To my knowledge. 2 CHAIR NORMAN: Taking that into consideration, 3 would you foresee exceeding an injection rate of 3,000 barrels 4 a day at any point? 5 MR. ELLER: I don't anticipate exceeding 3,000 6 barrels per day, sir. What the 3,000 barrels per day figure 7 was arrived at, in part, by looking at our various production 8 and the waste that we might generate, but also looking at 9 physically the equipment that we would have on location to do 10 the disposal, just physically how much would they be limited 11 to in terms of at full 24 hour disposal thawing (ph). 12 CHAIR NORMAN: Obviously, it's a significant 13 concern to the Commission to insure that there is what I'll • 14 refer to, as some confining layer or interval, so that the 15 injected fluids remain where are they injected, and the 16 application indicates that you're relying on these coal seams 17 to insure that there will not be an upward vertical migration. 18 The modeling that you did bring in several worst cases, is 19 there -- is there anything that's not addressed in that 20 modeling that might occur within the range of operating 21 probability, such as an increased pressure, increased volumes, 22 anything that might affect that? 23 MR. ELLER: Well, the increased pressure is, 24 for instance, will be something that we could note as taking 25 place during disposal operations. And certainly there is the 411 II METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 16 410 410 • 1 potential for something unforeseen happening, but specifically 2 where -- were the injected fluids to breach a barrier. There 3 should be a fairly notable pressure anomaly that would occur 4 that should signal to the injection operator that, you know, 5 something has changed and we need to investigate it before 6 continuing any further disposal. 7 CHAIR NORMAN: And that would be monitored and 8 then reported fairly expeditiously to the Commission? 9 MR. ELLER: Absolutely. 10 CHAIR NORMAN: Yeah. So, we would not 11 anticipate excessive pressures? 12 MR. ELLER: And Unocal as an operator would be 13 watching the pressure trend over time because there is -- • 14 it's as much in the trend of the pressure as it is at the 15 absolute magnitude of the pressure. 16 Furthermore, we would be, you know, instructing and 17 educating the field operators, the guys that actually would be 18 operating the pumps and doing the disposal operations on, you 19 know, what to look for that would be indications of a problem. 20 I'm not sure if I fully addressed your question 21 though, Commissioner? 22 CHAIR NORMAN: No, you did. You certainly 23 did. You did a good job of it because it was not a precise 24 question. So, I think you did a very good job of addressing 25 it. I have a somewhat hypothetical question that I would like • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 17 • 1 to ask you and then ask you to do your best to answer it 2 Assume that you and your family lived above the 3 injection well and that you had a water well that was down to, 4 let's say, seven or eight or nine hundred feet, and that your 5 family derived daily their drinking water from this well, 6 would, in your honest and professional judgment, would you 7 feel your family was safe being atop this injection zone and 8 taking water from an aquifer that was -- would be several 9 thousands of feet up the column, but would you be comfortable 10 that you'd have enough of a barrier there in these coal seams 11 that it would prevent some upward migration and these fluids 12 getting into your family's drinking water? 13 MR. ELLER: Yes, sir. • 14 CHAIR NORMAN: Your answer is yes? Is that 15 right? 16 MR. ELLER: Well, yes, the answer is yes, but 17 I was going to elucidate a little bit more, the -- I do feel 18 comfortable with that for really two reasons here. I'm 19 confident -- as an engineer, I'm confident in the modeling 20 that I've seen and I've personally done enough fracture 21 stimulation work that I'm comfortable with the confinement of 22 the fluids in the NNA #1 well as we permitted. But as a 23 subsequent barrier, if you will, the NNA #1 is at annular 24 injection down the surface casing to a depth of, I believe, 25 2,140 feet is the depth of that surface casing shoe, so that • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 18 411 110 • 1 annular disposal has been going on for some time, from 2,140 2 feet down. All indications are that that has been a very 3 outstanding barrier to vertical growth. And it alone, it 4 seems to meet all the parameters of being a very stable 5 barrier to containment for protection of fresh waters. 6 CHAIR NORMAN: Sure. And I appreciate that 7 answer, and I also recognize that the case I put to you is an 8 extreme one of hypothetically someone living right above the 9 injection well. But also, on the annular injection that you 10 mentioned, that volume had limit and now it's at an end, this 11 will be somewhat open- ended. 12 MR. ELLER: That's true. 13 CHAIR NORMAN: And right now we don't know the 14 volume, so it is conceivable -- I don't know that that annular 15 injection answers everything because that was of a discrete 16 volume and this volume, I would anticipate, theoretically over 17 time, could considerably exceed the volume put down the 18 annulus? 19 MR. ELLER: Sure, you would have to assume 20 that. All I'm saying is, that I take comfort in the fact that 21 there was a significant volume that was disposed of, be the 22 annulus and the -- the treasure logs seem to indicate with 23 beyond any doubt that they are very well contained right 24 there. So, it's just a back up, if you will, that I don't 25 have to rely only upon my engineering judgment and assessment • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 19 411 411 • 1 in this -- in this specific disposal interval, which I'm 2 confident in that aspect too by the way. 3 CHAIR NORMAN: But I guess, not to belabor the 4 point, but as to this particular injection order, the 5 Commission will be looking to the coal seams as the confining 6 layer that will prevent an upward -- that fracturing in an 7 upward migration of injected fluids, is that correct? 8 MR. ELLER: That's -- I would agree with 9 that, yes, sir. 10 COMMISSIONER SEAMOUNT: Mr. Chairman, I would 11 like to comment on that. Normally when we look for confining 12 layers, we look for types, claystones, shales, mudstones, this 13 is sort of a new concept to us to be relying on coals, and ill 14 what I would ask would be, would it be helpful for the record, 15 for Unocal to provide a series of depths that contain not only 16 coal intervals, but mudstone, clay, silt -stone intervals that 17 could provide service confining layers, or aqui - cludes (ph), 18 is a more recent term I've heard? 19 CHAIR NORMAN: I think that's an extremely 20 useful suggestion. I'd leave it to the Applicant, if that's 21 within your ability to provide it, what we're looking for are 22 some stops here so that if the fluid did somehow find a 23 pathway and begin to migrate upward, that we would have 24 several safety intervals along the way that would prevent this 25 from getting into safe water -- or fresh water, I'm sorry. • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 20 • 1 • 1 COMMISSIONER SEAMOUNT: I believe that in the 2 past we've gone as simple as say, the interval from here to 3 here, some depth contains these many net feet of mudstones, 4 claystones and shales, and these many net feet as -- as coal, 5 would be more than enough to confine the waste. 6 MR. ELLER: All right. If I understand what 7 the Commissioner's are asking for, it's in the NNA #1 well, 8 from well log data, observed intervals that Unocal senses 9 would be -- would constitute confining zones, have some 10 confining capacity. Likely to be coals, perhaps there are 11 shales, claystones and mudstones as well that can be 12 identified. 13 And specifically, are you thinking in the few hundred • 14 feet just above the disposal interval, or what portion of -- 15 of the well bore were you thinking? 16 COMMISSIONER SEAMOUNT: I would think that 17 because you're showing possible fracture heights, I'd at least 18 start above the worst case and go down to the top of the sand. 19 MR. ELLER: Yeah. 20 COMMISSIONER SEAMOUNT: Does that sound right, 21 Mr. Crandall? 22 MR. CRANDALL: Just bear in mind that under no 23 circumstance can you fracture the confining zone. Basically, 24 we're asking you to define the confining zone, and under no 25 condition can the confining zone be fractured. • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 21 • 1 CHAIR NORMAN: The record should reflect that 2 Mr. Robert Crandall, senior geologist for the Commission was 3 the person just speaking. Thank you, Mr. Crandall, for that 4 comment. Mr. Eller, do you have some sense of what we're 5 MR. ELLER: I believe so. 6 CHAIR NORMAN: Okay. 7 MR. ELLER: And I don't think this should be 8 difficult to come up with. 9 CHAIR NORMAN: And if we leave the record open 10 for ten days, will that give you sufficient time to provide 11 this? 12 MR. ELLER: That should be sufficient, yes, 13 sir. • 14 CHAIR NORMAN: Okay. Anything else, 15 Commissioner Seamount? 16 COMMISSIONER SEAMOUNT: Yes. I had one last 17 question for Mr. Eller. 18 CHAIR NORMAN: Okay. 19 COMMISSIONER SEAMOUNT: Unocal applied for a 20 disposal injection order for the Coho #1 a year or two ago, 21 was that well ever converted? 22 MR. ELLER: No, sir. It's my understanding 23 that there are problems with the lease agreements there that 24 are such that it's unlikely that it's going to happen. 25 COMMISSIONER SEAMOUNT: That brings up an METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 22 • • 1 interesting concept. If production stops at Happy Valley, you 2 still want to use it to dispose of waste from other areas, I'm 3 wondering -- well, that's a problem for DNR and Unocal. 4 CHAIR NORMAN: Well, presumably, you'd have to 5 have some right to be there, so at that point you would have 6 to rely on a separate agreement with the surface and sub- 7 surface owner to permit that. That would be my analysis of it 8 right now. Your lease is held in effect by virtue of being 9 committed to the unit, and in the future by complying with the 10 terms of the unit agreement leading up to production. 11 I think the case Commissioner Seamount raised is, is 12 what if production terminated then, what would be the status 13 of this injection well? And I think your right to be there 14 would either terminate or you would have to make a separate 15 agreement to continue to maintain that disposal well. 16 MR. ELLER: I believe, and I may be speaking 17 somewhat out of term, but I believe that Unocal already has 18 such an agreement in place that would allow this -- the NNA #1 19 well bore specifically to be used. Beyond that 20 COMMISSIONER SEAMOUNT: You're way ahead of 21 me. 22 CHAIR SEAMOUNT: And your agreement is with? 23 Do you know who that's with? 24 MR. ELLER: It's my understanding it's with 25 CIRI. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 23 • • • 1 CHAIR NORMAN: With CIRI? 2 MR. ELLER: That's my understanding. 3 CHAIR NORMAN: Okay. Good. So you have such 4 an agreement with CIRI, also notice has been given to the 5 surface owner, Ninilchik Native Corporation, and we've 6 received no objection from them. Good. 7 Mr. Eller, ordinarily at this stage of a hearing, what 8 we like to do is recess and then talk to senior staff to see 9 if they have any questions. I think in the interest of 10 economizing on your time, what we will do is go off the 11 record, but remain here and senior staff can let us know if 12 there's anything we've not adequately addressed. We don't 13 want to have to put you to the burden of coming back here • 14 again. 15 We'll go off the record for about approximately five 16 minutes. 17 (Off record) 18 (On record) 19 CHAIR NORMAN: We're back on the record after 20 being off record for approximately two minutes. The 21 Commission has determined that at this point we have 22 sufficient information to act on the application, other than 23 Commissioner Seamount's good suggestion that we supplement the 24 record with some additional information concerning potential 25 confining layers, such as mudstones, claystones, that would be METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 24 lio 1 1 at -- up the well at a lesser depth than the first proposed 2 injection interval. 3 And, it's my understanding, Mr. Eller, that you 4 believe ten days would be sufficient for you to review well 5 logs and for Unocal to provide that information to us? 6 MR. ELLER: That's correct. 7 CHAIR NORMAN: Very good. Then is there 8 anything further on this matter, Commissioner Seamount? 9 COMMISSIONER SEAMOUNT: The regulations may 10 require a lower confining zone too, is that correct? 11 MR. CRANDALL: That's correct. 12 COMMISSIONER SEAMOUNT: So, that would be just 13 a top -- a top or the bottom, a top of the bottom? • 14 MR. ELLER: Right. 15 CHAIR NORMAN: Thank you for that comment, 16 Commissioner Seamount. So, what the Commission is doing, and 17 in order to discharge our responsibility, is we would like to 18 know that the receiving intervals are bracketed top and bottom 19 with adequate confining layers. 20 MR. ELLER: Yes, sir. 21 CHAIR NORMAN: Okay. 22 MR. ELLER: I can supply that. 23 CHAIR NORMAN: Anything else, Commissioner 24 Seamount? 25 COMMISSIONER SEAMOUNT: Nothing more. • METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 25 • • 1 CHAIR NORMAN: Anything else before we excuse 2 Mr. Eller? (No response) And Mr. Eller, I again would like 3 to commend you, I think we see a number of applications and I 4 think this is an excellent job, and I think the brevity of 5 this hearing is a reflection of the fact that you and Unocal 6 have done a very good job in presenting this to us, and I 7 commend you. 8 MR. ELLER: You're very kind to say so. Thank 9 you. 10 CHAIR NORMAN: Without objection then, we will 11 adjourn this hearing at approximately 1:42 o'clock p.m. 12 (Off record) 13 4 1, 14 * * * END OF PROCEEDINGS * * * 15 16 17 18 19 20 21 22 23 24 25 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276 -3876 26 1 1 C E R T I F I C A T E 2 SUPERIOR COURT ) 3 ) ss. STATE OF ALASKA ) 4 5 I, Jerri Young, Notary Public in and for the State of Alaska, do hereby certify: 6 THAT the annexed and foregoing pages numbered 2 7 through 27 contain a full, true and correct transcript of the Public Hearing before the Alaska Oil and Gas Conservation 8 Commission, taken by Janice S. Scott and transcribed by Janice S. Scott: 9 THAT the Transcript has been prepared at the request of 10 the Alaska Oil and Gas Conservation Commission, 333 West Seventh Avenue, Anchorage, Alaska, 11 DATED at Anchorage, Alaska this 29th day of November, 12 2004. 13 SIGNED AND CERTIFIED TO BY: • 14 15 `` 1N111///j �� � ... .. 11„./4 �� L 16 +• + OTA,Q °, Jiri ri Young * � • = N. ary in ..: for tska 17 ' A BOG ' = My Commission Expi s: 1/31/08 18 o r . s z t 07A1 A‘V 19 20 21 22 23 24 25 410 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage; Alaska 99501 (907) 276 -3876 M • 0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Unocal DISPOSAL INJECTION ORDER NNA #1 November 9, 2004 at 1:00 pm NAME — AFFILIATION ADDRESS/PHONE NUMBER TESTIFY (Yes or No) PLEASE PRINT) \A, p n j\ N STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO.O2514019 AFFIDAVIT OF PUBLICATION PART 2 OF THIS FORM) WITH ATTACHED COPY OF ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 W 7th Ave, Ste 100 Jody Colombie October 7, 2004 ° Anchorage, AK 99501 PHONE PCN " - (907) 793 —1221 DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News October 8, 2004 PO Box 149001 Anchorage, AK 99514 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS g ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e- mailed Type of Advertisement X Legal n Display n Classified (Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE AOGCC, 333 W. 7th Ave., Suite 100 TOTAL OF PAGE 1 OF TO Anchorage, AK 99501 2 PAGES ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN 2 ARD 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LID 05 02140100 73451 2 3 '1 I' 4 ! REQUISITI ED B : ! DIVISION APPROVAL: \ IA f -- • Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Union Oil of California ( "UNOCAL ") for a Disposal Injection Order to allow the underground disposal by injection of Class II oil field wastes into the Unocal NNA #1 well, located in Section 11, Township 2 South, Range 13 West, Seward Meridian. Unocal by application dated October 1, 2004 and received by the Commission on October 4, 2004 has requested the Commission issue an order in conformance with 20 AAC 25.252 to allow the underground disposal by injection of Class II oil field wastes into the Tyonek Formation between the measured depths of 6,182 feet and 9,278 feet in the Unocal NNA #1 well. The Unocal NNA #1 well is a vertical well located 510 feet from the West Line and 272 feet from the south Line of Section 11, T2S, R13W S.M. The Commission has tentatively set a public hearing on this application for November 9, 2004 at 1:00 pm at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on October 25, 2004. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793 -1221. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West 7 Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on November 8, 2004 except that if the Commission decides to hold a public hearing, written protest or comments must be received no later than the conclusion of the November 9, 2004 hearing. If you are a person with a disability who m. nee• s• : 1. accommodations in order to comment or to attend the public hearin, 'lease tac of Colombie at 793 -1221. hn orman Chairman Published Date: October 8, 2004 ADN AO# 02514019 Anchorage Daily News 10/8/2004 Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD # DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 308491 10/08/2004 02514019 STOF0330 $175.20 $175.20 $0.00 $0.00 $0.00 $0.00 $0.00 $175.20 I Notice of Public Hearing STATE OF ALASKA STATE OF ALASKA . Alaska Oil and Gas Conservation . Commission ._ THIRD UDICIAL DISTRICT Re: The application of Union Oil of California 1 ( "UNOCAL ") for, a Disposal Injection Order to al- low the underground disposal by infection of Class Teresita Peralta, being first duly sworn on oath deposes and says I I oil field wastes into the Unocal NNA #1 well, lo- cated in Section 11, Township 2 South, Range 13 that she is an advertising representative of the Anchorage West, Seward. Meridian. ' Daily News, a daily newspaper. Unocal by application dated October 1, 2004 and received by the Commission on October 4, 2004 has requested the Commission issue an order in con That said newspaper has been approved by the Third Judicial formance with 20 AAC 25.252 to allow the under Court, Anchorage, Alaska, and it now and has been published in groiPhd divreo dt- by' inI#etlon of Class Pf oil field: - wastes into the Tyonek Formation between the the English language continually as a daily newspaper in measured depths of 6,182 feet and 9,278 feet in the Anchorage, Alaska, and it is now and during all said time was Unocal NNA4t1 well. The Unocal NNA #1 well is a �i g vertical well located 510 feet from the West-Line printed in an office maintained at the aforesaid place of and 272 feet from the south Line of Section 11, T2S, publication of said newspaper. That the annexed is a copy of an R13W S.M. advertisement as it was published in regular issues (and not in The Commission has tentatively seta public hear- . ing an this application for November 9, 2004 at 1:00 supplemental form) of said newspaper on the above dates and pm at the Alaska Oil and Gas Conservation. Com- that such newspaper was regularly distributed to its subscribers age5 Alaska 99501. A person may re t quest that the during all of said period. That the full amount of the fee charged tentatively scheduled hearing be held by filing a for the foregoing publication is not in excess of the rate charged a 30 on October 0liammission no later than . private individuals. If a request for a hearing is not timely filed, the Commission may consider the-issuance of on or- der without a, hearing. To learn-if -the Commission will hold the public hearing, please call 793=1221. In addition, a person may submit written com- ments regarding this application; to the Alaska Oil Signed E � and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Writ- ten comments must be received no later than 4:30 pm on November 8, 2004 except that if the Com- mission decides to, hold a public hearing, written protest or comments must be received no later Subscribed and sworn to me before this date: than the conclusion of the November 9, 200.4 hear- f } �C `/ ` ing. v ' - O C �hOA V r 0100 If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please contact Jody Co- Iambic at 793 -1221. Notary Public in and for the State of Alaska. J Chairman Third Division. Anchorage, Alaska ADN A O 0 obey 8, 2004 • MY COMMISSION EXPIRES: 07 • 00 k a/in s 9 14- , i< 2 1 ... . n■ es DV " . 44 "7, p ,:-Jr, ,,p -.1- • � ' iP ' T r • m. 'f RE: Another Notice • Subject: RE: Another Notice From: legalads <legalads @adn.com> Date: Wed, 06 Oct 2004 15:52:15 -0800 To: Jody Colombie <jody colombie(cadmin.state.ak.us> Hi Once Again Jody: Following is the confirmation information on your legal notice. Please let me know if you have any questions or need additional information. Account Number: STOF 0330 Legal Ad Number: 308491 Publication Date(s): October 8, 2004 Your Reference or PO #: 02514019 Cost of Legal Notice: $175.20 Additional Charges Web Link: E -Mail Link: Bolding: Total Cost to Place Legal Notice: $175.20 Your Legal Notice Will Appear On The Web: www.adn.com: XXXX Your Legal Notice Will Not Appear On The Web: www.adn.com: Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E -Mail: legalads @adn. com Phone: (907) 257 -4296 Fax: (907) 279 -8170 From: Jody Colombie Sent: Wednesday, October 6, 2004 12:14 PM To: legalads Subject: Another Notice «File: Ad Order form.doc» «File: DeepCreekUnit DIO.doc» 1 of 1 10/6/2004 3:59 PM 02 - 902 (Rev. 3/94) Publisher /.final Copies: Department Fiscal, Departmeleceiving AO.FRM STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO -02514019 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7th Avenue, Suite 100 Jody Colombie October 7, 2004 ° Anchorage, AK 99501 PHONE PCN M 907 - 793 -1221 (907) 793 -1221 DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News October 8, 2004 PO Box 149001 Anchorage, AK 99514 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS g ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he /she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for consecutive days, the last publication appearing on the day of , 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This day of 2004, Notary public for state of My commission expires 02 -901 (Rev. 3/94) AO.FRM Citgo Petroleum Corporation • Mary Jones • David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102 -6298 Houston, TX 77056 Kelly Valadez Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201 -3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401 -2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045 -0738 Portland, OR 97201 Seattle, WA 98119 -3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Baker Oil Tools • Cird Jill Schneider 4730 Business Park Blvd., #44 Land Department US Geological Survey Anchorage, AK 99503 PO Box 93330 4200 University Dr. Anchorage, AK 99503 Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508 -4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669 -7714 Soldotna, AK 99669 -2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K &K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 Williams Thomas North Slope Borough Arctic Slope Regional Corporation PO Box 69 Land PO Box Department Barrow, AK 99723 /� Barrow, AK 99723 76/7/7/' DIO NNA #1 • • Subject: DIO NNA #1 From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Wed, 06 Oct 2004 12:15:24 -0800 To: undisclosed-recipients:; BCC: Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor@alaska.net>, stanekj <staneicj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <roseragsdale@gci.net>, trmjrl <trmjrl @aol.com>, jbriddle <jbriddle@marathonoil.com>, rockhill <rockhill@aoga.org>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroletunnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, "Jerry C. Dethlefs" <jerry.c.dethlefs@conocophillips.com>, Bob <bob@inletkeeper.org>, tiv5t .',state.ak.usA bbriteh <bbritch@alaskamet>, mjnelson <mjnelson@purvingertz.com>, Charles ODonnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.mcom>, Collins Mount <collins_mount@revenue.state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <dougschultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yeln gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg,nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>; jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.nst>„eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dru Kurt E Olson <kurt_olson@legis.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_leman <loren_leman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian u bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska,com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Suzanne Allexan <sallexan@helmenergy.com>, „ ;; ' ' , Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com> 1 of 2 10/6/2004 12:15 PM DIONNA #1 • • Content -Type: application/msword DeepCreekUnit_DIO.doc Content- Encoding: base64 2 of 2 10/6/2004 12:15 PM Another Notice • • Subject: Another Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 06 Oct 2004 12:14:39 -0800 To: Legal Ads Anchorage Daily News <legalads@adn.com> Content-Type: application/msword Ad Order form.doc Content-Encoding: base64 Content-Type: application/msword DeepCreekUnit_DIO.doc Content-Encoding: base64 1 of 1 10/6/2004 12:15 PM Another Notice • • Subject: Another Notice From: Jody Colombie <jody_colombie @admin.state.ak.us> Date: Wed, 06 Oct 2004 12:13:48 -0800 To: undisclosed- recipients :; BCC: Angela Webb <angie Webb @admin.state.ak.us >, Cynthia B Mciver <bren mciver@admin.state,ak.us> Content -Type: application/msword DeepCreekUnit_DIO.doc Content - Encoding: base64 1 of 1 10/6/2004 12:15 PM r • UNOCA ' 7 j APPLICATION FOR A DISPOSAL INJECTION ORDER DEEP CREEK UNIT NNA #1 „_. I 0 1,_ • Wilaterafigi • ' tifitie. 417 t iP SEPTEMBER 2004 • • • APPLICATION FOR A DISPOSAL INJECTION ORDEFRECEIVED DEEP CREEK UNIT, NNA #1 WELL OPERATED BY UNION OIL COMPANY OCT 0 4 2LU4 Alaska Oil & Gas Can:. Commissiu This application was prepared in accordance with the requirements of Alaska 450 Gas Conservation Commission (AOGCC) Statute 20 AAC 25.252, Underground Disposal Of Oil Field Wastes And Underground Storage Of Hydrocarbons effective November 7, 1999. Introduction Union Oil Company (Unocal) is applying for a disposal injection order to allow for the underground disposal of oil field wastes in the Deep Creek Unit (Section 11, T2S, R13W, Seward Meridian). The injection order would approve disposal of Class II oil field wastes via injection through the Unocal NNA #1 well into Tyonek Sand intervals from 6,182 to 9,278 feet MD. The NNA #1 well is an exploration well which will be converted to a Class II well suitable for the disposal of oil field wastes as defined in 40 C.F.R. 144.6(b) (USEPA, 1998). Unocal has conducted testing and modeling that demonstrate that the proposed disposal operation will not allow the movement of oil field wastes from the Tyonek Sand into sources of freshwater. The construction of the NNA #1 well will isolate the disposal zone and protect freshwater resources. Unocal has also conducted testing which confirms the mechanical integrity of the production casing in well NNA #1. • Deep Creek Unit The Unocal NNA #1 well in the Deep Creek Unit (DCU) is located on the Kenai Peninsula approximately six miles east of the city of Ninilchik (see Figures 1 and 2). Ten other wells have been drilled in the DCU besides the Unocal NNA #1 as of August 1, 2004. Two of these have been permanently abandoned, one has been suspended, and seven await installation of a gas pipeline. There are currently no producing wells in the DCU, although operations are underway to begin gas production by the end of 2004. Table 1 summarizes the status of wells within the DCU as of August 2004. Figure 3 shows that no wells lay within a quarter -mile of the Unocal NNA #1. Table 1. Wells Within the Deep Creek Unit Perforated Perforated Well Spud Date Interval Interval Current Status MD SSTVD Standard Oil Deep Creek #1 3/19/1958 N/A N/A Plugged and abandoned I Superior Oil Happy Valley #31 -22 9/9/1963 N/A N/A Plugged and abandoned Unocal NNA #1 12/17/2001 6,182' — 9,647' 5,495' — 8,954' Class II disposal candidate Unocal Happy Valley #1 6/17/2003 7,978' — 10,730' 6,374' — 8,826' Awaiting gas pipeline Unocal Happy Valley #2 7/15/2003 6,784' — 10,052' 5,673' — 8,907' Awaiting gas pipeline Unocal Happy Valley #3 2/3/2004 9,228' — 10,678' 7,922' — 9,365' Awaiting gas pipeline Unocal Happy Valley #4 2/6/2004 8,854' — 9,888' 8,057' — 9,070' Awaiting gas pipeline Unocal Happy Valley #5 2/8/2004 N/A N/A Suspended Unocal Happy Valley #6 4/7/2004 10,854'- 10,882' 8,728' — 8,756' Awaiting gas pipeline ocal Happy Valley #7 6/15/2004 N/A N/A Awaiting gas pipeline vocal Happy Valley #8 7/20/04 N/A N/A Awaiting gas pipeline Disposal Injection Order Application - NNA #1 October 1, 2004 Application for a Disposal Injectioreder - Union Oil Company Page 2 of 6 Local, low -cost disposal of up to 3,000 barrels per day of produced water and drilling mud slurry is W necessary to have economic production of gas and conservation of resources from wells within the DCU. Permit Application The following summarizes the contents of the NNA #1 well permit application as they apply to the requirements found in 20 AAC 25.252 (c). Complete language for 20 AAC 25.252 is included in Appendix A of this document. (1) Location plat. Figure 3 shows the surface locations of wells (i.e., disposal and storage wells, abandoned or other unused wells, production wells, dry holes, or any other wells) within one - quarter mile of the NNA #1 well. As shown in Figure 3, there are no wells located within one - quarter mile of the NNA #1. Figure 4 is a plat showing the boundaries of the Deep Creek Unit, the location of the NNA #1 well (which will be converted to a Class II disposal well), and the other wells in the DCU. • A comprehensive list of freshwater wells in a 10 -mile radius of the NNA #1 well is listed in Appendix B. (2) List of operators and surface owners. Union Oil Company is the sole operator within a one - quarter mile radius of the NNA #1 well. The sole surface owner within a one - quarter mile radius of the NNA #1 well is the Ninilchik Native Association, Inc. • (3) Notification of operators and surface owners. The attached affidavit (Attachment 1) certifies that the Ninilchik Native Association, Inc., the sole surface owner within a one - quarter mile radius, has been provided a copy of this application for the disposal of Class II oil field wastes in the NNA #1 well. (4) Geologic Data. The Tyonek Formation consists of interbedded conglomerates, sandstones, siltstones, shales, and coals deposited in fluvial, lacustrine, alluvial, and terrestrial systems tracts. The reservoir qualities of the Tyonek within the Deep Creek Unit range from fair to poor, based on core studies of the Standard Oil Deep Creek Unit #rd1 located 0.35 miles to the southwest of the NNA #1 well. In the Standard Oil Deep Creek #1 rd core, the Tyonek sandstones consist of very fine to coarse grained sublitharenites with porosities ranging from 12% to 17.5% and permeabilities ranging from 2 to 10 millidarcies. The Tyonek sands are moderately feldspathic and Iithic, including K- feldspar, plagioclase, schistose and phyllitic rock fragments, chert, and occasional volcanic rock fragments. Other sandstone beds that were not cored in the Deep Creek Unit #1 well have better reservoir properties based on wireline logs, with porosities up to 22% and permeabilities exceeding 20 • millidarcies. Disposal Injection Order Application - NNA #1 October 1, 2004 Application for a Disposal Injectiorier — Union Oil Company • Page 3 of 6 • Confining strata for the requested Tyonek disposal zones consist of numerous coal beds that range in thickness from 6 inches to thirty feet or more, as well as tight carbonaceous "bone" beds and impervious claystone beds. The proposed injection intervals are individually perforated Tyonek Formation sands bracketed by the T -5 and T -105 intervals. These intervals, which occur from 6,182 to 9,278 feet MD (i.e. 5,495 feet SSTVD to 8,591 feet SSTVD) were perforated in 2002 and 2004 to test for natural gas. These zones failed to produce commercial gas rates but should serve as adequate Class II disposal intervals. Table 2 identifies the specific Tyonek perforation intervals in the NNA #1 well which have been identified for disposal. Table 2. Proposed Disposal Intervals in the NNA #1 p p Interval Perforated Perforated Name Interval Interval MD SSTVD T -5 6,182' — 6,222' 5,495' — 5,535' T -7 6,473' — 6,493' 5,786' — 5,806' T -12 6,752' — 6,772' 6,065' — 6,085' T -90A 9,170' — 9,183' 8,483' — 8,496' • T -100 9,206' — 9,234' 8,519' — 8,547' T -105 9,268' — 9,278' 8,581' — 8,591' (5) Logs. • The Togs of the Unocal NNA #1 well are on file at the AOGCC. • (6) Demonstrating mechanical integrity of casing and tubing. The NNA #1 well met the mechanical integrity requirements of 20 AAC 25.412(c) during a test conducted on August 23, 2004. A copy of the report from that test is presented in Attachment 2. A wellbore schematic diagram and a description of the construction of the NNA #1 well are shown in Attachments 3 and 4. In accordance with 20 AAC 25.412(b), the 3 -inch tubing used in well NNA #1 is rated to a burst pressure of 10,160 psi, which is over twice the maximum anticipated injection pressure of 4,200 psi. The packer is located at 6,097 feet MD, which is 85 feet above the uppermost perforation of the proposed disposal interval. Schlumberger's Ultra Sonic Imaging Tool (USIT) was run in the NNA #1 well in January 2002 to determine the adequacy of the cement sheath in the vicinity of the proposed disposal interval. An independent analysis of the findings of the injectivity test is presented in Attachment 5. The analysis concluded that the cement sheath around the 7" casing is sound below 5,860 feet MD. This is easily sufficient cement to prevent movement of fluids behind the 7" casing from the uppermost perforated interval at 6,182 to 6,222 feet MD. The procedure for testing the mechanical integrity of the casing and tubing after receiving the disposal injection order is provided in Attachment 6. This is the same procedure that • was conducted on August 23, 2004. As per 20 AAC 25.412(e), notice of a mechanical integrity test will be made prior to beginning injection to allow a representative of the Disposal Injection Order Application - NNA #1 October 1, 2004 Application for a Disposal Injectio• der — Union Oil Company • Page 4 of 6 • Commission to witness the test. Furthermore, as per 20 AAC 25.420(a), Unocal shall provide the Commission with 10 days notice before beginning injection operations into the NNA #1. (7) Description of oil field wastes to be injected. This Class II well will be primarily used for the injection of formation fluids (produced water, natural gas condensates, etc.) from nearby gas production wells. Unocal requests permission to dispose of approved Class II fluids from other Unocal operated fields as well. These fluids are completely compatible with fluids in this formation. Typical Class II wastes requested for injection include: drilling, completion, workover, and production fluids, glycol dehydration wastes, rig wash, drilling mud slurries, tank bottoms, NORM scale, precipitation within containment areas, and other approved Class 11 wastes. The above listed Class 11 wastes would be generated from drilling, completion, workover, and production operations. Current projections estimate that a maximum of 3,000 barrels per day of fluids will be injected. (8) Estimated pressure. The estimated average injection pressure will be 2,200 psig and maximum anticipated injection pressure will be 4,000 psig. (9) Evaluation of confining zones. Barree & Associates was contracted to model the hydraulic fracture characteristics of the planned injection operation in the NNA #1 well. The results of that work are presented in Attachment 7. A key component of the model was to determine if a fracture could propagate above the top of cement at 5,860 feet MD. The simulation was designed to simulate worst -case injection conditions from a fracture containment standpoint. The worst -case scenario was simulated by assuming the following conditions: • Only the uppermost set of perforations, in the Tyonek T -5 interval, was assumed to be open for disposal. Any fluids that enter deeper perforations reduce the potential for fracture height growth up from the T -5 perfs. • Disposal fluids were assumed to be laden with 12% solids (i.e. 3 Ibs of solids added per gallon of fluid) with a 30/50 sand mesh size. This approximates disposal of drilling wastes in a mixture of water, drilling mud, and cuttings. Solids tend to plug permeable pore throats and increase potential for fracture height growth. • A total of 8,000 bbl of fluids were disposed in a 2 -day continuous injection period. The volume of 8,000 bbl represents a high -side estimate of the volume of wastes that might be disposed during the drilling of a single Happy Valley well. Ordinarily, this volume of wastes would be disposed in batches over a two to three week period instead of continuously over two days. Injecting fluids in smaller volume batches allows more time for fluid leakoff which reduces net stress in the fracture. It should be pointed out that the simulated injection conditions exceed Unocal's projected maximum estimate of 3,000 bbl of fluids per day. • Experience has shown that adjacent coal intervals tend to impede fracture height growth in Tyonek sands. Several coals in the vicinity of the T -5 Sand are included • in the input data of the fracture simulator. But the averaging process of the simulator tends to reduce the stress contrast between these coals and the Disposal Injection Order Application - NNA #1 October 1, 2004 Application for a Disposal InjectioOder — Union Oil Company • Page 5 of 6 • surrounding formations, which reduces the degree of fracture containment predicted by the model. It is common for actual fracture containment to be better than predicted by the model in similar cases. Two different fracture simulation cases were made. The first simulation assumes all of the worst -case conditions listed above, but it also uses a rigorous engineering assessment of the strength of the bounding coal layers. This more rigorous assessment of the strength of coals in preventing fracture height growth has been proved valid in numerous radioactive tracer studies on the Kenai Peninsula during fracture stimulation. This more rigorous engineering model indicates that the coals immediately overlying the T -5 Sand will readily contain fracture height growth. A second fracture simulation was performed in which the strength of the coal layers was artificially reduced. Therefore, this simulation is intended to assess the absolute worst case fracture height growth that could be expected even if the coals are substantially weaker than indicated by the available data. In this second simulation, fracture does increase substantially in height but does not grow past the top of cement at 5,860 feet MD. In summary, all of the simulation work shows that fracture height growth is expected to be contained sufficiently by the coals adjacent to the Tyonek T -5 Sand. Fracture height is not expected to grow beyond the top of the cement sheath at 5,860 feet MD. However, recognizing the inherent limitations of fracture models, the author of the study suggests injection pressure characteristics that would be indicative of a fracture growing through the adjacent coal barriers. These worst -case models provide reasonable confidence that fractures will not propagate through the confining zones that might enable the oil field • wastes to enter freshwater strata. (10) Standard Laboratory water analysis. • • A laboratory water analysis of formation waters from the Tyonek T -5 Sand obtained from the Unocal NNA #1 well in April 2004 identified total dissolved solids (TDS) of 7,670.7 mg /I. This laboratory analysis is present in Attachment 8. (11) Freshwater exemption. The freshwater aquifer exemption application prepared in accordance with 20 AAC 25.440 was submitted to the AOGCC on August 4, 2004. (12) Well report for disposal zone. Figure 3 shows that no wells lay within a one - quarter mile radius of the NNA #1 well. The closest well is the permanently abandoned Standard Oil Deep Creek #1 rd well which is approximately 0.35 miles from the NNA #1 well. Prevention of Waste One of the charges of the AOGCC is to prevent waste of resources within the State. The NNA #1 well was originally drilled in exploration of natural gas. Extensive well testing operations in eight • different Tyonek sand bodies were conducted from January 2002 to April 2004 in an effort to Disposal Injection Order Application - NNA #1 October 1, 2004 Application for a Disposal Injectiorkder — Union Oil Company • Page 6 of 6 establish flow of natural gas. Throughout this testing, Unocal was unable to produce measurable ,quantities of natural gas from the NNA #1 well. The specific proposed disposal intervals in the NNA #1 well are those same Tyonek sand bodies that were unsuccessfully tested for natural gas. The NNA #1 well tested the north end of the greater Happy Valley structure, in a downthrown fault block that is separated from the gas- bearing portion of the Happy Valley field on the upthrown side of the fault. To date, three wells (Happy Valley #7, NNA #1, and Deep Creek Unit #1) have been drilled into this fault block and all three have failed to find or test commercial quantities of hydrocarbons. It is Unocal's opinion that the gas accumulation in the Happy Valley field is limited to the upthrown side of this fault. The gas accumulation is effectively sealed by the fault such that no gas is present on the downthrown side. Therefore, wastes that are injected via the NNA #1 well into this downthrown fault block will also be contained by the same fault that compartmentalizes the gas reservoirs. Unocal attests that no waste of natural resource of the State of Alaska will occur by approval of the proposed disposal interval in the NNA #1 well. In addition, injection of drilling wastes into the formations penetrated by the NNA #1 well will not compromise any of the known gas- bearing reservoirs in the Happy Valley field to the south. Conclusion • Unocal trusts that this application meets the requirements for a Disposal Injection Order as outlined in 20 AAC 25.252. • • • • 1 Disposal Injection Order Application - NNA #1 October 1, 2004 111 41/ List of Tables and Figures Figures Figure 1 — Cook Inlet Regional Overview Figure 2 — NNA #1 Local Vicinity Figure 3 — Surface Parcels within One - Quarter Mile of the NNA #1 Figure 4 - Deep Creek Unit Boundaries Attachments Attachment 1 — Affidavit of Notification of Surface Owners Attachment 2 — Mechanical Integrity Test Report of August 23, 2004 Attachment 3 — Schematic Diagram of the Unocal NNA #1 Attachment 4 — Description of Wellbore Construction Attachment 5 — Independent Evaluation of Cement Sheath Integrity Attachment 6 — Mechanical Integrity Test Procedure Attachment 7 — Independent Evaluation of Confining Zones Attachment 8 — Analysis of Produced Water from the Tyonek T -5 Sand Appendices • Appendix A — Complete Text of 20 AAC 25.252 Appendix B — Listing of Water Wells within Ten Miles of the NNA #1 • • Figure 1 HR -'. '�� v �6 . �� 'r !. -, - UNOCALQ i e ..F. COOK INLET �P e ' ; Regional Overview N � ` -. A , v . , ' r 10 5 0 10 1 .1 Mile `— —o� �� .io , z • • �� • Alaska State Plane Zone 4, NAD27 f r prepared by D. Rathert , 9/10/03 NIKISKI I . 4 I - - 1 yr . d ______I Jr r / ' .4 . r MAP AREA K E N A I CI I v.. STERLING fti , L lit , ,L 1 SOLDOTNA l /1111 J I i 1 I I KASILOF • , • CLAM GULCH. . . J, • f o J o , .. .. i _, 0 ., ,,, ,...._,_, r NINILCHIK' '0' HAPPY VALLEY T J r I I i ' -1 NIKOLAEVSK L , -. ANCHOR POINT / / f i , , HOMER Figure 2 �s . 1S14W • / 44/ • 1S13W 1S12W NINILCHIK - / i OILWELL NNA • 2S14Vd 2S13W 2S12W I UNOCAL2Z3 z7:5 NNA 1 Local Vicinity 3S14W 1.5 0.75 0 1.5 Miles Alaska State Plane Zone 4, NAD27 Figure 3 • • • 10 1 1 mile ANNA 1 DEEP CRK U 1/4 mile 2S 13W 15 UNOCAL NNA 1 Surface Parcels within 1/4 Mile 0.25 0.125 0 0.25 Miles Alaska State Plane Zone 4, NAD27 NNA 1 to Deep Crk U 1: 1767 feet Planar distance calculated within Alaska State Plane • coordinate system, NAD27 datum. 22 All parcels within 1/4 mile of well location owned by NINILCHIK NATIVE ASSOCIATION. Figure 4 • S NINILCHIK UNIT 1S13W 34 35 31 — — — — -— —� 1S12W 0 ,: S 4 5 I _0 8 9 12 I I — — — — *NNA 1 I *DEEP CRK U 1 -- 14 '3 3 2S14W $ *HAPPY V U 31 22 I 2S12W r 2s13 20 21 24 19 AREA OF PROPOSED *HAPPY VALLEY WELLS AQUIFER EXEMPTION - - - -` 27 26 25 30 29 23 `' 26 30 32 33 34 I 31 4 3 2 6 DEEP CREEK UNIT 7 I k 5 14 13 I 1 it 3 18 C------ - ----3 S -1,4W . S 13V+ 3S12W DEEP CRK U 1 21 9 _ 3 2 HAPPY V U 31 -22 1 HV1 - -____ HV2 1 HV3 i NIKOLAEVSK UNIT HV4 1 HV5----- -___�� V6 Al 2 1 0 2 DEEP CREEK UNIT WELLS ■ Miles June 1, 2004 Attachment 1 • AFFIDAVIT OF SERVICE BY MAIL • STATE OF ALASKA ) )ss. THIRD JUDICIAL DISTRICT ) J. Gary Eller, an employee of Unocal, Anchorage, Alaska, being duly sworn, states that on ( c;\r,Z.r \ , 2004, he mailed a copy of the "Application for a Disposal Injection Order for the NNA #1 Well in the Deep Creek Unit" to: Ninilchik Native Association Attn: Sandy Lee 701 W. 41 Ave., Suite 201 1 ` Anchorage, AK 99503 \ J. Gar Eller \ IL 4. . 1 • (name of affi. t) SUBSCRIBED AND SWORN to before me this \ day of C)C._+. , 2004. be • Notary Public in and for Alaska -My commission expires: '.{ 4q 4c PUBL1 , W° °� ° 4 P .. � / F ® p�0 � tl�o� Exp1Tef;' • Attachment 2 UNOCAL ALASKA RESOURCES WELL SERVICE REPOR• Date: 8/23/2004 _ Well Number NNA #1 • Work being done: MIT Location: Deep Creek Unit Supervisor: Rick Musgrove _ AFE# / Charge Code: 162680 Wireline Unit Number: Pollard Wireline Crew: Tree Valve Condition _ Total Wireline Miles: Fluid Level if Identified Max Depth (KB): Zero Wireline at: _ Well KB: Minimum Tubing ID: _ Max Tool OD: Start Tbg. & Csg. PSI Ending Tbg & Csg PSI Time Operation Details Inspect Unit X MIT X 10:45 MIRU methanol tank and triplex pump to 7" casing. RU 4000# pressure recorder. 11:05 Pressure test lines to 3000 psig. 11:10 Open valve to 7" casing. SITP = 0 psi, fluid level at surface. Start pumping methanol down casing. 11:24 Shut down pump and closed pump discharge valve, 3000 psi on 7" casing, approximately 100 gallons pumped. 11:54 Check pressure recorder, 2975 psi. 1155 RDMO location with methanol tank and triplex pump. AOGCC declined to witness MIT test. Sent in test ohart to Gary Eller (engineer). Depressure 7" casing. • Tool Cost Work String Detail: Description of any No tools or debris left in the hole: Brief Summary of Total Work Completed Ffotal Hours Worked Total Tool Cost Total Hour Cost Ticket # : _ Day # : Daily Cost: Cumulative Cost: WellDwntime Hr. Shut in H2S PPM Wire Test A v ed by: Code: ATTACHMENT #2 Attachment 3 • ATTACHMENT #3 • iftetirmera Well Name: NNA #1 Field: Deep Creek Unit UNOCAL 76 State: Alaska API: 50-133-20507 Conductor: 13 % ", 61 ppf, K -55 to AOGCC: 201 -215 71' 510' FWL & 272' FSL Sec. 11, T2S, R13W, SM Surface Casing: 9 % ", 47 ppf, L -80, BTC to 2140' RT -THF: 17.88' Cmnt with 145 bbl of 12.8 ppg lead and RT -GL: 16.6' 48 bbl of 15.8 ppg tail "G" Tbg lift threads - 3'W IBT Tree cxn - 2%" Bowen cxn R R IXI X Perfs: — T -5 6182' - 6222' (12 spf, 1/30/02) Production Tubing: 3 , 9.2 ppf, L -80, _ _ T -7 6473' 6493' (6 spf, 4/29/04) • IBT -Mod with SCC to 9586' _ — T -12 6752' - 6772' (6 spf, 4/29/04) T -90a 9170' - 9183' (6 spf, 4/29/04) q 4 T -100 9206' - 9234' (6 spf, 4/29/04) Completion - Chemical injection sidepocket mandrel at . .!� T -105 9268' - 9278' (6 spf, 4/29/04) 1953' ( ?) 9486' - 9526' (isolated, perf'd 1/26/02) Baker 70 -40 SC 1 packer at 6097' 9607' - 9647' (isolated, perf'd 4/3/02) - Baker CMU sliding sleeve at 6151(open) 2.813" X- profile X R - X- nipple at 6191' X ID= 2.813" - Baker 70-40 SC -1 packer at 9405' - Baker CMD sliding sleeve at 9426' (closed) 2.813" X- profile XX plug installed 3/18/04, capped w/ 20' of SafeCarb 500 - Baker 85 -40 F -1 packer at 9565' , - X- nipple at 9578' Production Casing: 7 ", 29 ppf, L -80, BTC to ID = 2.813" 9926' Wireline re-entry guide at 9586' Cmnt with 172 bbl of 11.0 ppg LiteCrete lead and 66 bbl of 15.8 ppg "G" tail. I I Production Liner: 3 % ", 9.2 ppf, L -80, ST -L Directional Data: liner from 9801' - 10578' vertical hole , , Baker ZXP packer, HMC liner hanger & tieback sleeve at 9801' PBTD = 9406' Cemented with 35 bbl of 15.8 ppg "G" TD = 10,590' • Drawn by: JGE Attchmnt 3 - NNA -1 schematic 6- 25- 2004.xls June 25, 2004 Attachment 4 • 411 Attachment 4 Well NNA #1, Deep Creek Unit Description of Wellbore Construction Surface Casing • 9%" OD, 47 ppf, L -80, BTC casing from surface to 2,140' MD. o Burst rating — 6,870 psi o Collapse rating — 4,750 psi o Pipe body yield — 1,086,000 lbs o Joint yield — 1,122,000 lbs • Cemented with 145 bbl of 12.8 ppg lead and 48 bbl of 15.8 ppg tail o Borehole = 12'/4" diameter o Cement returns to surface on December 20, 2001 o Formation leakoff test of 11.3 ppg EMW on December 23, 2001 after drilling to 2,162' Production Casing • 7" OD, 29 ppf, L -80, BTC casing from surface to 9,926' MD. o Burst rating — 8,160 psi 411 o Collapse rating — 7,020 psi o Pipe body yield — 676,000 lbs • o Joint yield — 718,000 lbs • Cemented with 172 bbl of 11.0 ppg lead and 66 bbl of 15.8 ppg tail • o Borehole = 8'/2" diameter o Cemented with significant losses on January 16, 2002 o Formation leakoff test of 13.1 ppg EMW on January 17, 2002 after drilling to 9,955' MD o Schlumberger USIT, CBT logs run on January 20, 2002. Top of cement identified at 5,860' MD. Production Tubing • 3'/2" OD, 9.2 ppf, L -80, non -upset IBT -Mod tubing with special clearance couplings run to 9,586' MD o Burst rating — 10,160 psi o Collapse rating — 10,530 psi o Joint yield — 159,090 lbs o Tubing annulus loaded with 9.0 ppg KC1/NaC1 brine with corrosion inhibitor o Baker 70 -40 SC -1 packer and seal assembly at 6,097' MD 4111 Attachment 5 • ALASKA 1/FULLING Scibilirpr • UNOCAL® To: Mr. Gary Eller UNOCAL From: Douglas Hupp, P.E. Principal Petrophysicist Schlumberger Subject: NNA #1 Cement Evaluation Report Date: 30- JUN -2004 Gary: This report reviews the cement evaluation logs for your well NNA #1 logged 20- JAN -2002. The information contained herein is organized as follows: • Description of data used in this report. • Description of well completion. • Description of cement evaluation tools. • Quality control review of cement evaluation logs used in this report. • Interpretation of cement bond quality based on available cement evaluation logs. Data Sources: UNOCAL has requested that Schlumberger evaluate the cement bond quality based on the Ultrasonic • Imaging Tool (USIT) and Cement Bond Tool (CBT) run in the 7 in. 29 lb/ft casing on their well NNA #1. Information used in this evaluation included USIT /CBT log from Schlumberger archive, well schematic, and daily operations report supplied by UNOCAL. The zone of highest interest to UNOCAL is in the vicinity of the perforations located at 6182 ft. Included as appendix A and B are the well schematic and daily operations report from 16- JAN -2004. Appendix C contains a tool sketch and appendix D presents the scales used on the USIT /CBT log presentation. Well Completion: At the time of the cement evaluation logging operations, the UNOCAL well NNA #1 was completed with 7 in. 29 lb/ft casing set inside a borehole drilled with an 8.5 in. drill bit. The cementing operation consisted of 172 BBL 11 PPG LiteCRETE lead cement slurry followed by 66 BBL 15.8 PPG tail slurry. Cementing operations occurred four days prior to running the cement evaluation Togs. The top perforations are located from 6182 ft to 6222 ft. Description of Cement Evaluation Tools: The cement evaluation tools utilized in this logging operation consisted of Schlumberger USIT and CBT tools. These tools were run in combination as presented in the Appendix C. The tool string included five centralizers with three positioned above and below the CBT tool and 2 positioned on the USIT tool. The USIT tool consists of a rotating transducer located at the bottom of the tool with centralizers and electronic section located above. The transducer emits ultrasonic pulses (200 kHz to 700 kHz) and receives the reflected signal from the casing wall. The resulting signal allows measurement of the following features: All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current price schedule. • • • Casing Internal Radius Two way transit time of ultrasonic signal being reflected off the casing ID Casing Thickness Resonance of signal inside casing Cement Bond to Casing Cement Impedance. The transit time and attenuation of the ultrasonic signal in the borehole fluid (mud) affects the returning signal used in the cement evaluation. To compensate for this, the mud travel time and impedance is measured while running into the well. These parameters are then used while recording the cement bond pass. The change in cement type from the LiteCRETE lead to the standard tail slurries is significant because they may have different impedance values, which can affect the interpretation. Cement acoustic impedance values vary with compressive strength, which can be dependent on time since cement was pumped, temperature, and other factors. In addition, the LiteCRETE cement typically has a lower acoustic impedance value than standard cement. The cement impedance value used on the field print for scaling the cement map display was 2.6 MRayl. This is a typical value used for USIT logs. Figure 1 presents an overview of the operation of the USIT tool. Figure 1— USIT Tool Overview Ultrasonic Imager* Tool • aenducar . [ het SI evaluates cement with . ,n ultrasonic transducer (O.2 — 0.7 MIIz) WNW The resonance technique ,.,,r, Casing Comerd 'Theft daee eoteies ei arpmm�ebe}y 7.5 revs per ' secerad and iz fired 2 tines (every 5 deg) per tn.Atlron A, 1 ----- %i • • • The USIT field print includes Cement Map and Bond Index presentations. Cutoff values are applied to the acoustic impedance values to generate these displays. Color coding for the different acoustic impedance values are presented below. Acoustic Impedance Value Bond Index Display Cement Map Display (MRayI) 0 — 0.3 Red (Gas) Red (Gas) 0.3 - 2.6 Cyan (Liquid) Cyan (Liquid) > 2.6 Yellow (Bonded) Graded Tan to Dark Brown (Bonded) Mico Debonded Green Green The green color indicates "Micro Debonded". Micro Debonded indicates small gaps in the cement that are not continuous over large intervals. These are typically gas filled and can be thought of as small dry micro - annulus with limited extent. The CBT tool responds to the attenuation of acoustic signal observed at the tools receivers that originates at the transmitter. The better the casing to cement bond, the greater the attenuation of the early acoustic signals seen on the receivers. Analysis of later acoustic signal arrivals can be used to identify the presence of formation signals further indicating bond quality. The variable density (VDL) display was presented on the cement evaluation log field print to aid interpretation of the CBT signal attenuation. Figure 2 presents a basic overview of the CBT measurement. Figure 2 CBT - Overview • Cement Bondi Log Casing a Mud A 20KHt Transmitter Bonded cement I 1 4 f► CBL amplitude 3 11 Reserver � ;b, ; ��' �.,,,•� ► • ;f:# R e eiver r" dot t` � Formation 0 100 Cerncnt CBL amp • • • • The USIT /CBT log presentation is organized as follows: Track 1 — Depth, GR, and cable speed. Track 2 and 3 — Measured internal and external radius of the casing from USIT. Track 4 — Raw acoustic impedance map from USIT. Track 5 — Minimum, average, and maximum acoustic impedance from USIT. Track 6 — Processed acoustic impedance map from USIT. Track 7 — USIT formation bond presentation from USIT. Track 8 — VDL display from the CBT. Quality Control Evaluation: A quality control review of the USIT /CBT logs indicated the following features: Feature Discussion Recorded mud The field engineer recorded the mud travel time while running into the well. Travel time travel time USIT. increases with depth as expected varying from 175 µsec /ft at 2000 ft to 170 µsec /ft at TD. The correct selection of mud travel time affects the casing ID calculations. Recorded Mud The field engineer recorded the mud impedance while running into the well. The impedance Impedance USIT. increases with depth as expected. The recorded impedance is higher than the theoretical values for the mud density recorded on this log. This is typically caused by mud separation while logging the mud properties or non - standard mud. If the mud liquids separate from the mud solids on the target plate while logging fluid properties, the recorded mud impedance value can be too high. • The field engineer used a mud impedance value of 2.56 MRayl and a cement impedance value of 2.6 MRayl for the entire log section. Measured casing The measured casing ID and thickness appear correct on this log indicating the engineer used the ID and thickness correct mud travel time parameter. USIT. VDL inspection The VDL signal from the CBT tool indicate sections of well bonded casing identified by strong CBT formation signals with little casing arrivals and sections with poor to no cement identified by large amplitude casing signal and no discernable formation arrivals. This log exhibits this range of character. • • • Interpretation: The cement bond interpretation is presented below. 8880 ft to TD Excellent casing to cement bond. Average cement impedance greater than 6 MRayl. Strong formation signal and little to no casing signal on the VDL display. The 66 BBL of tail slurry should theoretically fill the annulus to 8831 ft, which is close to this boundary. 8690 ft to 8880 ft Poor casing to cement bond. Strong casing arrivals and poor formation arrivals on VDL display. Average attenuation down to 2 MRayl. The cement attenuation change above 8880 ft may partly be due to change in cement type. 8380 ft to 8690 ft Good casing to cement bond. Average cement impedance between 6 MRayl and 8 MRayl. VDL display shows formation signal along with casing signal. 8190 ft to 8380 ft Excellent casing to cement bond. Average cement impedance greater than 6 MRayl. Strong formation signal and little to no casing signal on the VDL display. 8040 ft to 8190 ft Good casing to cement bond. Average cement impedance between 6 MRayl and 8 MRayl. VDL display shows formation signal along with casing signal. 7560 ft to 8040 ft Poor casing to cement bond. Strong casing arrivals and poor formation arrivals on VDL display. Average attenuation down to 1 MRayl. 6070 ft to 7560 ft Good casing to cement bond. Average cement impedance between 4 MRayl and 5 MRayl with isolated zones approaching 3 MRayl. VDL display shows formation signal along with casing signal. Occasional zones indicate free pipe for short intervals (see 7325 ft to 7345 ft). 5860 ft to 6070 ft Good casing to cement bond with possible micro annulus. Average cement impedance grades from 4 MRayl to 2 MRayl. Casing arrivals start to appear on the VDL display but formation arrivals can still be seen later in time. Above 5860 ft Free pipe. The VDL display indicates free pipe with no formation signal. The average cement impedance is close to 2.5 MRayl. This impedance value rises slightly at shallower depths, which gives the appearance of cement in the USIT cement map display. This is probable due to mud property variations with depth. The cement bond quality around 6182 ft is of special interest to UNOCAL as this is the top perforated zone in this well. The description below concentrates on the interval from 5700 ft to 6182 ft. This 322 ft zone covers the interval from the top perforations to the free pipe signal described above. Figure 3 presents this section of the cement evaluation log. I IC I • 0 • • Figure 3 - USIT /CBT Cement Evaluation log 5700 ft to 6200 ft with annotated features. Mir "MEM MINIM * ' yy � iti■■ '. � 1 swims s►sa�� . Free Pipe 1 B1111111111 : r " , i • • . - ''\•'' itfIEN . . '''.:•':' , t ... ' • � \; M TMI 4 :. c V ■ #i�W■■ % - 1 4 -, , iti y�t s 'Vail/ . . ' ■lil{ -1•■ . . 1111 !1?i ■■ ; `z • i O ' i , I Free Pipe ■ \fa!■ ... • • 1111111111 1 a 1 r r 3111, . lf1R_'! •� 1 I • ' t • ` • ' 6551! A '' , 1 ' • rr'I ' . 1 4,i +` tI 1 e� • '.. I Free Spots i .- n ���� ,i■ • 'r, I • Cement 71E4■■ , 1 P . •••, _ .. L ME , , �"'w ■S■ Formation • 3 i'? 'I .•, I ■lJt1I .'• Signal ' • y I` • .r . _ . E q• , ' ` • �. .V .� la 14 .4.E .` MI — I MEM MitililiiM OMEN Average cement impedance ranges from 6 MRayl at the bottom to 2.2 MRayl at the top of this interval. The 2.2 MRayl identified at the top indicates free pipe with the bottom section (6 MRayl) indicating good • • bonding between the casing and cement. The cement map indicates occasional small isolated free pipe sections below 5970 ft with larger free pipe intervals occurring at 5930 -5944. Above 5830 ft the casing appears to be free with little to no cement evident on the cement evaluation logs. Formation signals can be seen on the VOL display below 6075 ft along with casing arrivals. The presence of formation signal on the VOL display suggests at least fair to good bonding with a possible micro annulus at the casing to cement interface. From 6075 ft to 5855 ft the formation signals are less prevalent but can still be seen on the VOL display. Above 5855 ft, the VOL display indicates free pipe with little or no formation signal. In conclusion, the cement bond appears to be good below 5860 ft. The occational discontinuous free pipe spots do not appear to be continuous or interconnected. Above 5860 ft the casing appears to be free with little to no cement present. S • . • Appendix A Well Schematic 0 • • • • ,:. Well Name: NNA #1 ALASKA MRILLING Field: Deep Creek Unit UNOCAL 76 State: Alaska API: 50- 133 -20507 I Conductor: 13? ", 61 ppf, K -55 to AOGCC: 201 -215 71' 510' FWL & 272' FSL Sec. 11, T2S, R13W, SM Surface Casing: 9? ", 47 ppf, L -80, BTC to 2140' RT -THF: 17.88' Cmnt with 145 bbl of 12.8 ppg lead and RT -GL: 16.6' 48 bbl of 15.8 ppg tail "G" Tbg lift threads - 3' /z' IBT Tree cxn - 2'h" Bowen cxn 1 ■ X X Perfs: T -5 6182' - 6222' (12 spf, 1/30/02) Production Tubing: 3' /z ", 9.2 ppf, L -80, T -7 6473' -6493' (6 spf, 4/29/04) IBT Mod with SCC to 9586' T -12 6752' - 6772' (6 spf, 4/29/04) • T -90a 9170' 9183' (6 spf, 4/29/04) Completion T -100 9206' - 9234' (6 spf, 4/29/04) ►M T -105 9268' - 9278' (6 spf, 4/29/04) Chemical injection sidepocket mandrel at 1953' ( ?) ∎ -∎ • • • 9486' - 9526' (isolated, perfd 1/26/02) - Baker 70 -40 SC -1 packer at 6097' 9607' - 9647' (isolated, perfd 4/3/02) - Baker CMU sliding sleeve at 6151(open) 2.813" X- profile ►�� - X- nipple at 6191' X ID = 2.813" - Baker 70-40 SC -1 packer at 9405' - Baker CMD sliding sleeve at 9426' (closed) 2.813" X- profile XX plug installed 3/18/04, capped w/ 20' ►�� of SafeCarb 500 - Baker 85-40 F -1 packer at 9565' I - X- nipple at 9578' Production Casino: 7 ", 29 ppf, L -80, BTC to ID = 2.813" 9926' Wireline re -entry guide at 9586' Cmnt with 172 bbl of 11.0 ppg LiteCrete lead and 66 bbl of 15.8 ppg "G" tail. Production Liner: 3W, 9.2 ppf, L -80, ST -L Directional Data: liner from 9801' - 10578' vertical hole , ■ Baker ZXP packer, HMC liner hanger & tieback sleeve at 9801' PBTD = 9406' Cemented with 35 bbl of 15.8 ppg "G" TD = 10,590' Drawn by: JGE NNA -1 schematic 6- 25- 2004.xls June 25, 2004 • r • Appendix B UNOCAL Daily Operations Report 16- JAN -2002 • • Daily Operations Report • Illett i!r4DDR7 *Date: January 16, 2002 Well Name: NNA - 1 UNOCAL® Report #: 36 Platform: Field: Deep Creek Rig: H & R Rig # 9 DrIg Contractor: H & R • Project Objective: Evaluate Tyonek ( primary ), Beluga and Sterling ( secondary ) gas reservoirs AFE #: 152340 Spud Date: 12/17/2001 Present Depth: 9,935 ft RKB Height (ft): 19.55 AFE Cost: Project: 36 days hrs Drilling Hours: - hrs Last BOP Test: 1/16/2002 Daily Cost: F /Spud: 30 days 13.5 hrs Footage Drilled: 0 ft Pressure (High): 5,000 Previous Cum: Current Hole Size: 8.500 inches Average ROP: - ft/hr Pressure (Low): 250 Cumulative Cst: HES Comments: Unocal foreman slipped (on Herculite ) and fell, striking head. Examined by doctor - slight concussion. Returned to work. Days Without Accident: 22 1 Spills: 0 1 Spills to date: 0 I AM Drill: 1 PM Drill: Safety MTGS.: Pre -tour safety meetings both crews. Present Operation: RIH with BHA # 8 and (6" bit) to 5500' at 05:00 hrs Casing Shoe/Tubing Information: Slow Pump Rates: Size lb/ft MD TVD LOT /PPG Pump: Total POB: 27 Drilling 1: Jim Benson 13 3/8" 61 71 71 n/a SPM 76 DRLG: 11 Catering: Foreman 2: Russ Grainger 9 5/8" 47 2,140 2,140 14.0 Press: Prod: Welders: Tool Pusher: Jerry Otto 7" 29.0 9,927 Liner: Rig Cont: 16 Other: Strk: Boats: 0 Helicopters: 0 Depth L -U -P From To HRS Operations Detail P 0:00 0'30 0.30 Continued working 7" csg to 9928' and circ'ing bottoms up ( to clean up well ). P / U - +/- 220K S / 0 - +/- 180K. Losses - O to 2 BPH. P 0:30 1:00 0:30 Shut down pumps - well flowing back at high rate - decreasing. Broke out and laid down 1 jt of 7" csg. P / U Cameron hanger with 11.5' pup jt below and landing jt above. M / U to 7" csg. Landed hanger in wellhead. ( 7" shoe at 9926.5'. 7" float collar at 9834.5' ). P 1:00 2:00 1:00 L/D Lafleur fill up tool. R/U cementing head & equipment. P 2:00 3:00 1 00 Broke circ (a) 70 SPM 777 psi. Pre - cement safety mtg. Stopped circ. Pumped 5 bbls water & press test lines 3500 psi - OK. Pumped 30 bbls of 11 PPG MudPush. ( Dropped bottom plug ) P 3:00 4:30 1'30 Worked on #1 cement silo (plugged) - could not get cement out of silo. • P 4:30 5:30 1 00 Started cementing operations - all equipment functioning. Mixed and pumped 172 bbls of LiteCRETE lead cement slurry mixed A 11.0 ppg. Followed with 66 bbls of tail cement slurry mixed (a) 15.8 ppg. P 5:30 7:00 1 30 Dropped bottom plug. Displaced with rig pump. (Utilized rig pump for displacement due to low mud volume supply to cementing unit.) Displaced with 360 bbls of 10.4 ppg mud at +/- 6.5 BPM, 330 psi increasing to +/- 1750 psi. Reduced pump rate to 2 BPM at 1365 psi last 2 bbls pumped. Bumped plug to 1900 psi. and held 5 min. Released press - floats holding. ( Had +/- 75% returns while mixing / pumping cmt, reducing to +/- 50% returns while displacing cmt. And continuing to reduce to +/- 33% at end of displacement. Lost 110 bbls while pumping cmt. Lost 241 bbls while displacing cmt. Total losses - 351 bbls. CIP at 06:50 hrs P 7:00 10'00 3:00 Observed annular flow at end of cement job. Closed annular preventer, pressure built to 25 psi and held. R / D cement lines, L/D bales, spiders, elevators, cement head, landing joint, stabbing board & adjusted top drive torque rail. ( Opened annular after 2 hrs ( 25 psi on annulus ). Press to zero. Had slight flow then stopped ). P 10:00 12:00 2:00 P/u two (2) stands of HWDP, installed pack -off, tested 11" X 7" pack -off to 5000 psi for 15 min. OK, L/D tools P 12:00 12'30 0.30 Performed injectivity test down 9 5/8" X 7" annulus. (Pumped 25 bbls 10.4 ppg mud (a) 1.9 bbl /min - max pressure 255 psi, gradually reducing to 225 psi and steady. P 12:30 13:00 0:30 Rigged down injection line to annulus. P 13:00 14:00 1.00 Changed 7" rams to 4" rams. P 14:00 17:00 3:00 L/D 5" HWDP, 6 3/8" drill collars, 6" combo jar P 17:00 20:00 3:00 P / U test plug on test jt and set - ok. Press tested BOPE - Top and bottom rams, Blind rams, HCR and manual valve, Kill valves, 250 / 5000 psi., Hydril to 250 / 3500 psi. P 20:00 0:00 4:00 Test choke manifold valves, floor valves to 250 / 5000 psi. Set wear bushing. Test top -drive valves and to 250 / 5000 psi. Blow down TDS. ( Performed Koomey test ). • Mud lost to the hole today. 429 bbls Total mud lost to the hole this section 650 bbls. MomingReporl -NNA -1 01- 18- 02.zis Page 1 Or 2 Revised 10/28199 by MWD Daily Operations Report III je 411/Date: January 16, 2002 Well Name: NNA - 1 UNOCAL® Report #: 36 411 MW TMP ViSC Gels API W p c Chlr CA corrected Solids 3 6 100 200 300 600 Fluid Type PPG (f) sec VP 10 Gels F.L. MBT H /32 6 % KCL Flo Pro 10.4 64 68 22 13 2/5/9 4.8 e9 6.5 9s l 1 146000 160 11 2 3 16 26 35 57 Sample Loc.: Trip units Connect. Gas: unitsIMAX. Gas: units IBKGND. Gas: units Bit # Size MF Type Serial Depth (ft) Dist Rotate ROP Condition (in) Number From To Hrs (ft/hr) I 0 D L B G 0 R 5 8- 15/32" DBS CD 93 ( core bit) 4980986 8,855 8,945 90 5.5 16.0 1 1 NO A X N NO 1D 6 8 1/2" IITC MX -09 DX (3 -14's) V45DA 8,945 9,935 990 32.4 30.5 2 4 BT M E 1 WT TD 7 6" SEC FM2643 5011873 BHA From To Length Flow Press Description I Hours on Jars: 88.3 NO (kips) kgpm) (psi) 7 8,945 9,935 905.90 30 347 2,750 8 1/2" cone bit + 8 1/2" FG -NBS + XO + Daily Shock Sub + XO + 8 1/2" FG -IBS + XO + C.D.R. + Power Pulse + XO + A.D.N. w/ 8 1/4" STAB + (2) 6 3/8" DC's + (1) 6 3/16" DC + (1) 6 7/16" DC + XO + (1) 5" HWDP + 6 1/2" Combo Jar + XO + (20) 4" HWDP 8 9,935 1062.33 6 "PDC bit+ NBS+ Pony Collar+ IBS+ 2 x 4 3/4" DC's+ IBS+ 11 x 4 3/4" DC's+ XO + combo jars+ 20 X 4" HWDP + 4" HT -38 DP to surface. Weight -On -Bit Average: Kips Maximum: Kips Rotating: Kips Sliding: - Kips Drag Values: PU: Kips SO Kips ROT: Kips Torque Values: On: ft-Ibs Off: ft-lbs Max: ft-lbs Rotating Values: DP: Motor: rpm Total: rpm Top Drive Information: MD Incl. Azimuth TVD MD Incl. Azimuth TVD MD Incl. Azimuth TVD MD Incl. Azimuth TVD 7,360 2.42 169.59 7,350 8,478 2.79 163.70 8,467 9,592 4.80 150.04 9,578 7,639 2.33 169.15 ' 7,629 8,850 3.64 161.95 8,838 9,847 4.86 150.41 9,832 , 7,917 2 59 166.40 7,906 9,127 4.24 157.71 9,114 9,870 4.78 150.54 9,855 8,198 2.64 159.00 8,187 9,320 4.80 151.19 9,307 III 1 Rig Equipment Down: None. Total Rig DWN Time: 4.50 hr s� Walk- About: Slipping hazards on Herculite covered with snow cannot be stressed too much. 00:00 to 05:00 Summary: 00:00 - 00:30 Clear floor of test equipment. Bring handling tools for BHA # 8 to floor. 00:30 - 02:00 PU Bit #7 and BHA #8 02:00 - 02:30 Retape TDS service bundle canvas. Service rig and break circulation. 02:30 - 05 RIH on 4" DP to +/- 5500' at 05:00 hrs. General Comments, Planned Operations, Notes,...etc: Cost report for today does not include 7" csg / equip and Cameror wellhead equip. Will adjust on tomorrows report • Mom/ngReporl -NNA -1 01 -16-02 rls Page 2 of 2 Revised 10/28/99 by MWD • • Appendix C Tool Diagram SURFACE EQUIPMENT W DM-AB STM -C QSR -U/Y WITM (CTS) -A DOWNHOLE EQUIPMENT LEH-Q 66.7 LEH - 0 CAL -Y CCL 1 63.5 64.5 CAL-Y TCC -BF 61.0 ECH -KC n TCC-BF TelStabu s _ 56.0 SGT -L Gamma Ray _ 57.1 98.0 SGH -K SGC -SA. SGD- TAA AH -178 52.5 CST -EB 51.5 CME -AT CBC -EB ECH -VC CME-AU CBS-DA CIVE-AT • UTR1 33.0 UTR2 r 32.2 UTR3 al .7 F2R3 30.5 LTR1 30.0 LTR2 29.1 LTR3 26.6 DLAG _ 25.2 AH -178 LI 21.5 US IT -A 20.5 ECH -MRA USI C-A USI S -A USRS -B Control Ultrasoni 04 DF USI Reid HV +• 0 Ten510 11 TOOL ZERO MAXIMUM STRING DIArJETER 4.65 IN MEASUREMENTS RELATIVE TO TOOL ZERO ALL LENGTHS IN FEET • • • • Appendix D Cement Evaluation Log Scales Micro-debon dn. Gas or Dry McroA ' Liquid di Internal Mn d Internal ws (IRMN) radius (IRMN) Bonded (IN) 2.5 2.5 (IN) 4 External Internal radius Casa Dry Gamma radius Maximum of AI Maximum McroA Ratio Pay ( Average R (AIM) GAS (GAP I) (ERAy) Q f') ■ , 'MRAv 10 S — f Iu• 4 ON) 2.5 2.5 QM 1 (----) 0 Cable ii 'let ra:: aorus Internal radius Mcrodebondi Average of Al Speed (CS) Maximum Average IA ng Ratio (A V) 0 (F N 2000 4 Q ON) 2.5 2.5 (IN) 4 0 (MRAY) 10 1 ( (D-- 0 -1000.0000 400 500 03000 0.5000 20000 t 0000 aooce 1 5000 150W 20000 10000 25000 45000 3.0000 SD000 05000 55000 CCL Internal radius External radius 0550D Minimum of Al "ow Mn Amplitude Max (CCLU) Average Average SDDDD (AIMJ) 70000 QRAV) (ERAV) s room Sanic_VDL Curve (VDL) III ( - - - -) 55000 0 (MRAY) to 20 2i' 4 (IN) 2.5 2.5 ON) 4 8.500) 200 (US) 1200 7. 7.5000 Cement Map sOW a0000 with Impedance Raw Acoustic Classification Imped. (AIBK) (Al_MICRO ( - - - -) DEBONDING IMAGE) ( - -- -) , x1m 1 11110 Attachment 6 ATTACHMENT 6 • • NNA #1, Deep Creek Unit Mechanical Integrity Test Procedure Class II Disposal Well Objective: Perform a mechanical integrity test on the 7" casing in the NNA #1 well as per the regulations of 20 AAC 25.412(c). Procedure: 1. Notify AOGCC representative of intent to perform MIT within 24 hours. If applicable, cease annular disposal operations into the NNA #1 well for several hours prior to MIT to allow temperatures and pressures to stabilize. 2. RU test pump with methanol source onto the 7" casing. RU a 2 -pen chart recorder or SPIDR gauge to allow MIT to be recorded. 3. When AOGCC representative arrives, pressure test 7" casing to 3,000 p si for a minimum of 30 minutes. (Note: Once the 7" casing if full it should take approximately 2.3 bbl to pressure up to 3,000 psi. Contact Completion Engineer if excessive volume is needed to reach 3,000 psi.) • 4. When MIT is complete, bleed annulus pressure to 1,500 psig. Document successful MIT test on appropriate AOGCC form and mail to Completion Engineer. • J. Gary Eller August 9, 2004 Attachment 7 • . UNOCAL® UNOCAL NNA #1 Cutting Disposal Evaluation R. D. Barree Barree & Associates LLC September 10, 2004 A prediction of expected fracture height growth for a cuttings disposal project in the NNA #1 well, Happy Valley field, was requested by Gary Eller of UNOCAL Alaska. Data used for the analysis were supplied by UNOCAL and consist of wellbore completion diagrams, digital well logs, and some observed injection pressure data. These data were incorporated into the analysis, along with experience gleaned from observed behavior of other Beluga - Tyonek fracture treatments. • 1 • • le ka n Well Name: NNA #1 • Field: Deep Creek Unit UNOCAL® State: Alaska I 1�F ('y$ API 50- 133-20507 Conductor 137',61 ppf. 6-55 to A. \.,. .: A0GCC 201 -215 ' ]1' (4.__ — _._..._ FSL 510' FW T2S. 277 6 3W. Sec 11, T2S, 13W, SM Surface Casino BOO tp 2140' RT -THF 1]68' CmM ' W O 1452 8 ppg lead and 15 8 pp RT -GL 166' 48 bbl of 15 8 769 18.1 Tbg LB threads • 3'5' IBT Tree con - 2'h' Bowen con 67.211 gra Perk T -5 6182' - 6222 (12 spf. 1/30/02) PrMarhon Talmo, 3'h'. 9 2 ppf, L-80. T -] 64]3' -6493' (6 spf.4129 /04) IBT -Mod 880 SLCto 9588' T -12 6]52 - 6]]7 (6 spf, 4/29/04) 7.90e 9170' - 9183' (6 spf, 4/29/04) T -100 9206 - 9234' (6 s01 4/29/04) Completion 0-105 9266 - 9278' (6 SPf, 4/29/04) - Chemical injection sdepocket mandrel at O1GI g486' - 9528' (isolated. pd 628/02) 1953' (T) 9607' - 9647' (isolated, perfd 4/3/02) - Baker 70-40 SC-1 packer at 6997' • Baker CMU sliding sleeve at 6151(opan) 2613 X-profile 11A 61 - X -nipple at 8191' D =2813' _ - Baker 70-40 SC-1 packer at 9406 - Baker CVO sliding sleeve at 9426' (closed) 2 813' X -pfofile XX plug installed 3/18/04, capped w/ 20' of 85-40 F-I b 500 - Baker 85-40 F -1 packer et 9565' - X -nipple at 9576 Pmdnrtinn Casino T, 29 ppf. L-80, ETC to ID = 2 813' 9926 - reentry guide at 9586 le Lmn with 172 bbl of 11 0 ppg g 19" C a ad and 86 EDI of 15 8 pp'G lei! Production Liner 3'S', 92 PS, LAO, ST -L Directional Magi liner from 9801' - 10578' vertical hole Baker ZXP packer, HMG hner hanger tieback sleeve at 9601' PBTD =9406' Cemented with 35 bbl 0115 1,09'0' TO = 10,590' Copvnght BRA 2004 • The welibore completion diagram for the NNA #1 well is shown. For the cuttings disposal project only the T -5 perforations, at 6182 -6222' were assumed to be open. If any of the lower perforations are open, the predicted fracture geometry will differ from the results presented here. By assuming only the top perfs are open, the results of this study present a "worst case" for upward fracture growth. Cuttings disposal is expected to be via the existing 3.5" tubing. 2 • • • - - - 7 ':',.' ' - E�= 585000 =2M ti X . -Z - _ NNA #1 Processed ..t .„... = 5. 5. . --_ ".. Log Data : . — X 00 , ' --""_ � = - __ � 610660 - ' 7i = — 6,50.00 a = �__ - =�= X — -- _ - 6182 -6222' 630000 =MSW 6%600 NEI 600 — o _ 1 .7,- am - ��� _i j = 6450.60 - ' FM - 6500.00 L: .�� M - -- ,. = 666000 -: �_Mr* - -- E ttz . woo co : - � :x. 6750.00 i .. � m � �� a � _ ma 660000 ��� _ 6850 a�.0 OM - - r- 69000 ' ' . te = a � Copyright B&A 2004 • The digital log data consisted of density, resistivity, and sonic (shear and compressional) measurements across the zone of interest. The logs were processed assuming minimal tectonic influence on the in -situ stress field, and using a normal pore pressure hydrostatic gradient. Various correlations were used to cross -check the consistency of the log data. Some discrepancies were noted in the reported shear -wave arrival times in the upper section of the well (5850- 6050'). The reason for the inconsistency is not clear but could be related to borehole conditions. A borehole caliper log was not included in the log suite. Because of these data problems the Poisson's Ratio calculated from DTC and lithology was used instead of that obtained from the measured Vp/Vs ratio. The figure also shows the location of the perforation set that was assumed to be open for the cuttings disposal project. • 3 • • 41, - , , =a = PR Calculations f sa " = for NNA #1 - --, h , --- - _ = _� 5956 - - -� = ! F s 600000 s yr 4600. ! "' - SS - liiiiS7 a 6100 00 or -.....amp ■■■••■..i.■••=agowa. _� 6150.00 '_.'l4.m34°_ 6i 67n6 Bzso.a6 i _� s Em ram e65o. .� _ 6400 00 . Q- . - _ - .1 3�� EMI 6460.0 �C x� i,� "06.60 -s— __._ F 6160.00 '� I = _ €09=== `s �. ■ -7_ " � ti— raer-W _ " . __- . Ti _ • 6650 00 a' 670000 y7" '...:.==='.. 6750 .00 - _ii'.I ' 6800.00 — � C i t iorii 6650.60 i,_. =_ _ 0000 i ��1i .11 - . — � - �sst��i s 6860.60 __ . _ - ^ ? .�.��ZK�� Copyright B&A 2004 7000 00 _ • The log display shows the computed value of Poisson's Ratio (PR) from the measured DTC and DTS data (PRACT), and three other correlations. Note that all the curves agree over most of the logged interval, except for the zone between 5850 and 6050'. In this interval the PRDTC value was used instead of the PRACT. This choice was based on experience in other wells in the area. The estimation of PR is important in predicting fracture height because it provides the primary control of the variation in in -situ horizontal stress input to the model. • 4 • • Assumed Input Data for NNA #1 MA D isposal Model 1 Pore pressure gradient normal (0.44 psi /ft) *Cuttings slurry injection rate = 2.5 bpm *Total slurry volume = 8000 bbls Open perfs at 6182 -6222' *Cutting slurry density = 10 ppg . 3 lb cuttings added per gallon . Solids Volume Fraction =12% Injection pressure 1800 psi at 2 bpm Cement top at 5860' Copyright BRA 2004 The assumptions used for the cutting injection project are listed in the figure. The actual grind of the cutting is not known, so a 30/50 mesh distribution of sand was used to simulate the cuttings. The base -fluid used in the model represents a dilute drilling mud, such as may be formed by adding water to the mixture of cuttings and mud solids. The critical limit for upward height growth is set at 5860', which is just below the top of the modeled interval. This represents the top of competent cement in the well. If the fracture grows above this depth it may communicate to the wellbore and expose the open annulus to injection pressure. • 5 t► NNA #1 Model Zonation a N. ,mAr.R MOP rvo. i1o.rt lvon Cmt Top 8600 5600 6600 6000 5000 - 1000 6000 5100 .100 B100 -,. 6100 _—.61d1=11111.1111111111• - 6�1 0 g100 6100 5300 _..._ 6300 3400 6400 540 - 1 6400 9600 5600 6600 - -- - - - Copyright 60.0 2004 • The log data were imported to the simulator and averaged over a 20' node height. This provides the spatial resolution for tracking the fracture growth with time. The figure shows the spacing of the nodes used for the numerical model solution. The left track shows GR and the coal flag. The right track shows the computed total fracture closure stress. Significant coals are marked at far -right in black. The top of cement is indicated. • 6 • • WinGOHFER Design Pumping Schedule: NNA #1 Cutting Disposal Project Prop Prop Clean Flud Slurry Acid % Dirty Stage Cum Cum Cum Stage Cum Design Name Conc. Vol. Name Rate Type Acid Vol Time Time Slurry Clean Prop Prop Ilb/gall (gall Ibpml (gall (mini Inl (gall 10 (lb) Ilb) 1 Brady Sid 30/50 300 33600 00 Cuttngs Skory_150 0 na_0 250 NONE 0 00 38175.19 363.57 36357 38175.19 33600 00 100800.00 100800 00 2 Brady Sand 30/50 000 2500.00 Cuttings Skory_1500 rna_0 250 NONE 0 00 2500.00 23.81 387.38 40675.19 36100 00 0.00 100800.00 3 Brady Sand 30/50 300 33600 00 Cuttrgs Slury_150__0 0 250 NONE 0 00 38175.19 363.57 750.96 78850 38 69700 00 100800 00 20160000 41080Jy Said 30/513 000 2500 00 Cuttings Slurry _150_0 na_0 250 NONE 0 00 2500 00 23.81 774 77 81350 38 72200 00 0 00 201600.00 5 Brady Sand 30/50 no 33600.00 Cuttings Slurry_150_0 na_0 250 NONE 0.00 38175.19 363.57 1138 34 119525 60 105800.00 100800.00 302400.00 6 Brady Sad 30/50 000 2500.00 Cuttings Slury_150_0_na_0 250 NONE 0.00 2500 00 2381 116215 122025 60 108300 00 0 00 302400.00 7 Brady Sand 30/50 3 00 33600.00 Cuttings SMmy_150_0, na_0 250 NONE 0.00 3817519 36357 1525 72 160200 80 141900 00 100800.00 403200.00 8 Brady Sad 30/50 0 00 2500.00 Cuttings Skary_150_0 na_0 250 NONE 0.00 2500 00 2381 1549 53 162700 80 144400 00) 0.00 40320000 9 Brady Sand 30/50 300 33600.00 Cuttings Slrry_150_0 na_0 250 NONE 0.00 0017519 36357 191311 200876.00 178000.00 10080/00 504000.00 10 Brady Sad 30/50 0 00 2500.00 Cuttings Skrry_150_0_nna_0 250 NONE 0.00 2500 00 2381 1936 92 203376 00 180500 00 0.00 50400000 11 Brady Sand 30/50 3 00 33600.00 Cuttings Shary_150 0 na 0 250 NONE 0.00 3817519 363 57 2300 49 241551 20 214100 001 100800.00 604800 00 12 Brady Sand 30/50 000 2500.00 Cuttings Slurry 150_0 na 0 250 NONE 0.00 2500 00 2381 2324 30 244051 20 216600 00 0.00 604800.00 13 Brady Sand 30/50 3 00 33600.00 Cuttings Slrry_150_0_na_0 250 NONE 0.00 3817519 363 57 2687 87 282226 40 250200 00 100800.00 705600.00 14 Brady Sand 30/50 000 2500.00 Cuttings Skary_150_0_na_0 250 NONE 0.00 250000 2381 271168 28472640 252700 00 000 705600.00 15 Brady Sand 00/50 no 33600.00 Cutups Skary_150_0 na 0 250 NONE 0.00 3817519 36357 3075.25 322901 60 286300.00 100800.00 006400.00 16 Brady Sand 30/50 0.00 250000 Cuttings S6ary_150_0_na_0 250 NONE 0.00 2500 00 2381 3099.06 325401 60 288800.00 0.00 806400.00 17 Brady Sand 30/50 3 00 33600 00 Cuttings Skary_150_0_na_0 250 NONE 000 3817519 363 57 3462 64 36357680 322400 00 100800 00 907200 00 18 Brady Sand 30/50 0.00 2500 00 Cuttings Skary 150_0 na_0 2.50 NONE 0.00 2500 00 2381 3486.45 36607680 324900.00 0.00 907200.03 19 Brady Sand 30/50 3.00 3360000 Cuttings Skrry ,.150_0 na_O 250 NONE 0.00 3817519 363.57 3850.02 40425200 358500.00 100800 00 1008000.00 20 Brady Sand 30/50 000 2257 00 Cuttings Sl rry_150_0_na_0 250 NONE 0 00 2257 00 21 50 3871.51 406509 00 360757.00 0.001 1008000 00 21 Brady Sad 30/50 000 10 00 Cuttings Slurry 150 0 na_0 0.00 NONE 0 00 10 00 10 00 3881.51 40651800 360767 00 0.00 1008000 00 Copyright B &A 2004 The pumping schedule for the disposal used for the modeling is shown in the table. This schedule injects 8000 barrels of slurry at 2.5 bpm. Periodic wellbore sweeps of clean fluid (no cuttings) are included after every 800 barrels of clean - fluid injection. In past injection projects these sweeps have helped to prevent solids buildup in the wellbore across the perforations, and have helped maintain a stable injection pressure. Slide Generated using WINPARSE Version 2000.2.22 Data Taken From the following WinGOHFER Output file: c: \GohWin \Unocal Disposal \Disposal 7 • • • WinGOHFER Input Data: Data: Va NNA #1 High - Stress Coal Model n ! „:x, n N ...r.s Pmwms R.m 103rmntl, GanmehYV 1610m z91) Paw010 20 ro0.al Tw sxen 023B 30 io 5106 ui Wet Va107,...1 Iasane11001.1 OM C— MOM - 7 - 7s'T _ n moan M°°` i L - # L ,. - --�— o �tom ii 1 soon _ -I -_-„c , - T _ 1 — ;71 1 I 11111= ®, 1 — 1 1 1 1 • Prior experience in fracturing the Beluga - Tyonek interval has indicated that coals in this area appear to act as substantial barriers to fracture height growth. The input data in the figure is based on the processed log data as obtained directly from arithmetic averaging over the 20' node height used in the model. In the case of thin coals, the averaging process reduces the contrast between the coals and surrounding formations and reduces the degree of fracture containment predicted by the model. It is common for actual fracture containment to be better than predicted by the model in similar cases. The total closure stress profile, that controls fracture height growth, is dependent on pore pressure, Poisson's Ratio, and Biot's Poroelastic constant in cases with no tectonic effect (as assumed here). For the model case shown only the Biot's constant values have been changes to reflect a higher degree of containment in the coals. In the default processing Biot's constant is a function of effective porosity, defined as the neutron - density crossplot porosity corrected for shale volume- fraction. Because of their low density, coals appear to have an anomalously high porosity and low GR reading, hence low apparent shale volume. This leads to an estimated effective porosity that is far too high. This known error in processing justifies the slight downward revision in the estimated Biot's constant. Slide Generated using WINPARSE Version 2000.2.22 Data Taken From the following WinGOHFER Output file: c:\GohWin_Data\Unocal_NNA_Disposal\Disposal_continuous.bin 40 8 • • Expected Treating Pressure for WA High- Stress Coal Model Rees. h & rrs GOHFER Bottom Hole Pressure (Psi) A i 1 1 R wrC.r Pry >m: p�n - GOHFER Slurry Rate (bpm) B B C A GOHFER Bottom Hole Prop Cone (lblgall — C 6000 3.0 — 3.5 5000 nnr �t����il iI r �I ii �u�i�i 2.5 -3.0 —2.5 111 2.0 — 2.0 3411 1.5 — 1.5 2441 111/1111111 1.0 1000 0.5 _0.5 0 0.0 —0.0 00:00 08:00 16:00 00:00 08:00 16:00 00 9 910 141970 :00 08:00 16:00 00:00 1 �990 12;wlo 1/3 Time Copyright B&A 2004 • Using the adjusted input log data, the total 8000 barrels of slurry was disposed of in the well. The plot shows the expected treating pressure behavior for the project. The small wellbore sweeps are indicated by the drop in injected solids loading. Over the course of the disposal, the treating pressure fluctuates but the trend maintains a nearly constant value. I 9 S Proppant Volume Fraction (Cuttings): NNA #1 High- Stress Itiet Coal Model Proppant Volume Fraction (Brady Sand 3080) 387234 Minutes spa TVD.Tf 5960f Inn illimma N ± 70766 0156 022E75 0305 03B125 0.4575 0937501 Copyright B&A 2004 • The figure shows a profile view of the created fracture at the end of the disposal. The bounding coals contain fracture height growth for this case. The created fracture half - length is approximately 2500 feet. The magenta color represents a settled -bank of solids in the fracture. Later fluid over -rides this settled bank because of the lower density of the injected slurry compared with the dehydrated cuttings bed. Slide Generated using WINPARSE Version 2000.2.22 Data Taken From the following WinGOHFER Output file: c: \GohWin_ Data \Unocal_NNA_ Disposal \Disposal_continuous.bin • 10 0 . • WinGOHFER Input Data: tri&A NNA #1 Low - Stress Coal Model oi.Raw 101]mLL� Pwne.fily (410m 292 ovaroOg mua) Roc.. Zone f341 77 ha 58541 t .u. ....(. .aR1256ti J2 r:9: 611 n_ti.. +l •. vm Bud I mOB51 Loremene10 00ro1 071 -:-J s Symnl I MOM y l ■ lr I �- — — — �C ' �� Sg1011� ' di DOR J I I I �_. 4 T J 5 �i 1 I 1 f 1 � 1 1 J i I— I 1 , — I 1 r �1 I — I --1-1 1 1 I I �„ 1�f��i - — y • The "worst case" for height containment is to use the arithmetic averaged log input data with no correction to Biot's constant in the coals and no correction for thin -bed effects in the coals. The figure shows the discretized model input data for this case. Slide Generated using WINPARSE Version 2000.2.22 Data Taken From the following WinGOHFER Output file: c: \GohWin_ Data \Unocal_ NNA_ Disposal \Disposal_continuous.bin • 11 • • • Treating Pressure Response for ItittAt Low - Stress Coal Model GOHFER Bottom Hole Pressure (psi) — A GOHFER Slurry Rate (bpm) A GOHFER Bottom Hole Prop Cork (Ib /gall t B C 12000- -3.0 -3.5 10000- 2.5 3.0 -2.5 8000- - 2.0 -2.0 A _ 6000- 9 -1.5 - 1 1.5 4000 -1.0 2000- �� = 0.5 JJJ 0.0 -0.0 00:00 08:00 16:00 00:00 08:00 16:00 00:00 08:00 16:00 00:00 1/1/19)0 1/2'1910 1/3/19)0 1/4/19)0 Time Copyright B&A 2004 • The model treating pressures for the case of poor coal containment is shown in the plot. As the fracture height grows, dehydration of the slurry is accelerated. This causes increased buildup of the solids bank across the perforated interval, leading to a higher injection pressure. Over time the increased injection pressure drives continued height growth. At the end of the job the pressure exhibits several periods of rapid increase followed by sharp drops. These events correspond to break -downs of discrete coals and are evidence of height - growth events. • 12 0 • • Cuttings Concentration (Ib /ft 11645cA NNA #1 Low - Stress Coal Model Proppant Concentration pnm^2) 3811.72 Minutes 4nn �, Ma II we - -). 11111 / 4 r - rimm. U 61206 i QM 61186 8 � S i i s 74421153 0®42307 ' 11 145 176&15 221a577 2 652692 1E64607 9 Even using the worst -case input data, the top of the created fracture at the end of injection is at or below the expected top of cement. The figure shows the solids distribution in lbs/sqft over the created fracture surface. In this case the created fracture half - length is about 600 feet. Slide Generated using WINPARSE Version 2000.2.22 Data Taken From the following WinGOHFER Output file: c: \GohWin_ Data \Unocal_NNA_ Disposal \Disposal_continuous. bin • 13 Comments on NNA #1 Cuttings IAA Injection Disposal Project 4 The difference between containment and un- contained height growth is controlled primarily by the coal properties 40 Coals at this depth and in the Beluga - Tyonek interval do not behave elastically and their properties are difficult to determine from borehole logs • Experience in conducting hydraulic fracture treatments in this interval suggest that coals typically act as confining beds • The model results suggest that treating pressure behavior will be different for the two cases and may be used as a monitoring tool during injection If pressure increases, followed by sharp drops, are observed, then the fracture is experiencing periodic height - growth episodes and the injection should be curtailed • If treating pressure is stable or continuously increasing at a low rate, injection can be continued Copy fight E&4 :ON • As the model results show, very small changes in the assumed input data to the model have large effects on the results for this case. Observation of fracture growth in this interval in other wells strongly suggests that any errors in the input data tend to over - predict fracture height growth. Expected fracture geometry should more closely resemble the first case presented in this analysis. In any event, the predicted difference in treating pressure response can be used during the disposal operation to monitor the probable fracture geometry. If the treating pressure shows cyclic pressure increases and sharp drops, then the fracture is growing in height and is poorly contained. In this case injection should be constrained. If the pressure remains constant or rises steadily, with no obvious break - backs, then the fracture is growing steadily and is well contained and injection can continue. in either case, the use of periodic wellbore sweeps with clean fluid is recommended to keep the wellbore clear of settled solids. 41 Attachment 8 • • West Coast Region • 5125 Boylan Street Bakersfield, CA 83308 (661) 325-4138 Lab Team Leader - Sheila Hernandez (432) 495-7240 Water Analysis Report by Baker Petrolite Company: UNOCAL ALASKA RESOURCES Sales RDT: 31100 Region: ALASKA Account Manager: MIKE PING (907) 252 -4082 Area: KENAI, AK Sample #: 235940 Lease /Platform: NNA #1 Analysis ID #: 43437 Entity (or well #): 1 Analysis Cost: $40.00 Formation: TYONEK Sample Point: WELLHEAD Summary Analysis of Sample 235940 @ 75 °F Sampling Date: 4/30/04 Anions mg /1 meq /I Cations mg /I meq /I Analysis Date: 5/27/04 Chloride: 3060.0 86.31 Sodium: 1488.7 64.75 Analyst: JAMES AHRLETT Bicarbonate: 1375.0 22.53 Magnesium: 7.0 0.58 TDS (mg /I or g /m3): 7670.7 Carbonate: 0.0 0. Calcium: 55.0 2.74 Density (g /cm3, tonne /m3): 1.005 Sulfate: 63.0 1.31 Strontium: 3.0 0.07 • Phosphate: Barium: 2.0 0.03 Anion /Cation Ratio: 0.9999999 Borate: Iron: 60.0 2.17 Silicate: Potassium: 1557.0 39.82 Aluminum: Carbon Dioxide: Hydrogen Sulfide: Chromium: Oxygen: Copper: pH at time of sampling: Comments: Lead: pH at time of analysis: 7.77 Manganese: pH used in Calculation: 7.77 Nickel: Conditions Values Calculated at the Given Conditions - Amounts of Scale in lb/1000 bbl Gauge Calcite Gypsum Anhydrite Celestite Barite CO2 Temp Press. CaCO CaSO42H 0 CaSO 4 SrSO BaSO 4 Press °F psi Index Amount Index Amount Index Amount Index Amount Index Amount psi 80 0 0.78 29.22 -2.42 0.00 -2.49 0.00 -1.92 0.00 1.00 1.04 0.29 100 0 0.86 32.70 -2.44 0.00 -2.44 0.00 -1.91 0.00 0.86 1.04 0.41 120 0 0.95 35.48 -2.44 0.00 -2.37 0.00 -1.88 0.00 0.74 1.04 0.57 140 0 1.03 38.26 -2.44 0.00 -2.27 0.00 -1.85 0.00 0.64 1.04 0.77 Note 1: When assessing the severity of the scale problem, both the saturation index (SI) and amount of scale must be considered. Note 2: Precipitation of each scale is considered separately. Total scale will be less than the sum of the amounts of the five scales. Note 3: The reported CO2 pressure is actually the calculated CO2 fugacity. It is usually nearly the same as the CO2 partial pressure. III 0 • • Scale Predictions from Baker Petrolite A nalysis of Sample 235940 @ 75 °F for UNOCAL ALASKA RESOURCES, 4/30/2004 Calcite - CaCO3 Barite - BaSO4 2 - 350 D 1.8 2 350 D 1.6 - 1.6 300 0 1.6- 300 1.4 0 c 1.4 O • 1.2 - 250 ' m 1.2 250 1 2 1 - ° c 1 � 0.8 200 g) 200 . 0.8 (61/ o 0.6 d 2 0.6 d '� 0.4 150 m ' 0.4 150 `D • 0.2 6 3 0.2 6 i o 0 0 (1) -0.2 ,1 100 120 1. 0100 c 0") 0 4 . 100 120 1. 0100 c - 0.4 -0.6 50 Er -0.6 50 o- -0.8 - - - - --s- s -- -._._.. -_ a 0.8 -1 1 0 `" -1 - b - - 0 Temperature in °F Temperature in °F Gypsum - CaSO4 *2H20 Anhydrite - CaSO4 2 350 2 350 1.8 > 1 1.6 300 0 1 300 • 1.2 1a1 3 1.2 250 o c 1 250 0.8 200 c nmc6 200 O 0.6 m 1 o usv 0.2 150 v 150 0 N - 0 • � 100 o N _ ;1 100 120 1.0100 - 0.4�� 100 120 1 0 0 0 - 0.6 50 _ 50 -0.8 o- 0 1 - - - + - -- ♦ -- 0 ' -1 _ ♦ - -- ♦ - 0 Temperature in °F Temperature in °F Carbon Dioxide Partial Pressure Celestite - SrSO4 0.9 - 2 350 1.8 D 0.8 - -* 1.6 300 3 0 1.4 c c x • 0.6 - v 1 250 O 0.5 0.8 200 o . 0.4 - 0 0.6 n, 0.4 ciTi ' 0 iv- - 150 ' 0.2 io 0 0.2 - N -0 ^1 100 120 1. 0 100 0 0.1 - -0.4 -0.6 50 D 0 • -0.8 80 100 120 140 -1 - - ---∎ 0 4111 Temperature in °F Temperature in °F Appendix A 20 AAC 25.252 • APPENDIX A UNDERGROUND DISPOSAL OF OIL FIELD WASTES AND UNDERGROUND • STORAGE OF HYDROCARBONS. (a) The underground disposal of oil field wastes and the underground storage of hydrocarbons are prohibited except as ordered by the commission under this section. In response to a letter of application for injection filed by an operator, the commission will issue an order authorizing the underground disposal of oil field wastes that the commission determines are suitable for disposal in a Class II well, as defined in 40 C.F.R. 144.6(b) as revised as of July 1, 1998, which is adopted by reference, or the underground storage of hydrocarbons. An order authorizing disposal or storage wells remains valid unless revoked by the commission. (b) The operator has the burden of demonstrating that the proposed disposal or storage operation will not allow the movement of oil field wastes or hydrocarbons into sources of freshwater. Disposal or storage wells must be cased and the casing cemented in a manner that will isolate the disposal or storage zone and protect oil, gas, and freshwater sources. (c) An application for underground disposal or storage must include (1) a plat showing the location of all proposed disposal and storage wells, abandoned or other unused wells, production wells, dry holes, and any other wells within one - quarter mile of each proposed disposal or storage well; (2) a list of all operators and surface owners within a one - quarter mile radius of each proposed disposal or storage well; (3) an affidavit showing that the operators and surface owners within a one - quarter mile radius have been provided a copy of the application for disposal or storage; • (4) the name, description, depth, and thickness of the formation into which fluids are to be disposed or stored and appropriate geological data on the disposal or storage zone and confining zones, • including lithologic descriptions and geologic names; (5) logs of the disposal or storage wells, if not already on file, or other similar information; (6) a description of the proposed method for demonstrating the mechanical integrity of the casing and tubing under 20 AAC 25.412 and for demonstrating that fluids will not move behind casing beyond the approved disposal or storage zone, and a description of (A) the casing of the disposal or storage wells, if the wells are existing; or (B) the proposed casing program, if the disposal or storage wells are new; (7) a statement as to the type of oil field wastes to be disposed or hydrocarbons stored, their composition, their source, the estimated maximum amounts to be disposed or stored daily, and the compatibility of fluids to be disposed or stored with the disposal or storage zone; (8) the estimated average and maximum injection pressure; (9) evidence to support a commission finding that the proposed disposal or storage operation will not initiate or propagate fractures through the confining zones that might enable the oil field wastes or stored hydrocarbons to enter freshwater strata; • (10) a standard laboratory water analysis, or the results of another method acceptable to the commission, to determine the quality of the water within the formation into which disposal or storage is proposed; (11) a reference to any aplOble freshwater exemption issued in accor ce with 20 AAC 25.440; and (12) a report on the mechanical condition of each well that has penetrated the disposal or storage • zone within a one - quarter mile radius of a disposal or storage well. (d) The mechanical integrity of a disposal or storage well must be demonstrated under 20 AAC 25.412 before disposal or storage operations are begun, after a well workover affecting mechanical integrity is conducted, and at least once every four years. To confirm continued mechanical integrity, the operator shall monitor the injection pressure and rate and the pressure in the casing- tubing annulus during actual disposal or storage operations. The monitored data must be reported monthly on the Monthly Injection Report (Form 10 -406). (e) If an injection rate, operating pressure observation, or pressure test indicates pressure communication or leakage in any casing, tubing, or packer, the operator shall notify the commission by the next working day and shall implement corrective action or increased surveillance as the commission requires to ensure protection of freshwater. (f) The commission will require additional mechanical integrity tests if the commission considers them prudent for conservation purposes or protection of freshwater. (g) Modifications of existing or pending disposal or storage operations will be approved by the commission, in its discretion, under 20 AAC 25.507, upon application containing sufficient detail to evaluate the proposed modification. No modification will be approved unless the applicant proves to the commission that the modification will not allow the movement of fluids into sources of freshwater. (h) If wells, including freshwater wells or other borings, are located within a one - quarter mile radius of the disposal or storage well, are a possible means for oil field wastes or hydrocarbons to move into sources of freshwater, and are under the control of • (1) the operator, the operator shall ensure that the wells are properly repaired, plugged, or otherwise modified to prevent the movement of oil field wastes or hydrocarbons into sources of freshwater; or (2) a person other than the operator, the commission will not issue an order under (a) of this section to the operator until the operator presents evidence to the commission's satisfaction that the person who controls the wells has properly repaired, plugged, or otherwise modified the wells to prevent the movement of oil field wastes or hydrocarbons into sources of freshwater. (i) The commission will publish notice of the disposal or storage application and will provide opportunity for a hearing in accordance with 20 AAC 25.540. (j) If disposal or storage operations are not begun within 24 months after the approval date, the injection approval will expire unless an application for extension is approved by the commission. (k) The annular disposal of drilling wastes approved under 20 AAC 25.080 is an operation incidental to drilling a well and is not a disposal operation subject to this section. (I) This section does not apply to underground disposal that is regulated under 40 C.F.R. 147.101 by the United States Environmental Protection Agency. History - Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority - • AS 31.0:S.030 Appendix B ICI Wate Its Within 10 -Miles of the NNA #1 • • Dee k Unit APPENDIX B Kenai eninsula Borough, Alaska 23- Jun -04 WELL DEPTH TOWNSHIP & STATION ID SITE USE H2O_USE1 (feet) SECTION RANGE OWNER 600729151325001 Withdrawal of water Domestic 101.00 S05 T001S R013W S JONES DARREL &DRESSLER ROXANNE 600659151333801 Withdrawal of water Domestic 127.00 S05 T001 S R013W S WALLIS BOB 600601151344601 Withdrawal of water Domestic 55.00 S07 T001S R013W S JONES ALBERT 600553151345101 Withdrawal of water Domestic 58.00 S07 T001 S R013W S LENG FOSTER 600557151344601 Withdrawal of water Domestic 58.00 S07 T001 S R013W S THORNTON LEO 600624151334201 Withdrawal of water Domestic 48.50 S08 T001S R013W S ISSERMOYER CAROLYN 600550 1 51 344601 Withdrawal of water Domestic 110.00 S18 T001S R013W S PINNOW TAMMY &ROBERT 600521151364800 Commercial 0.00 S13 T001S R014W S WALDSMITH DARWIN E &KAYE S 600518151363401 Withdrawal of water Domestic 60.00 S13 T001S R014W S KIRKLAND • 600521151362401 Withdrawal of water Domestic 78.00 S13 T001S R014W S BROWN ERIC 600549151361301 Withdrawal of water Domestic 92.00 S13 T001S R014W S TIEMAN ERNIE 600517151364901 Withdrawal of water Domestic 160.00 S13 T001S R014W S MCCOMBS JOHN 600428151375001 Withdrawal of water Domestic 86.00 S23 T001S R014W S JOHNSON MELVIN 600439151371101 Withdrawal of water Domestic 35.00 S24 T001S R014W S JACKINSKY SHAWN &CINDY 600439151365701 Withdrawal of water Domestic 48.00 S24 T001S R014W S JACKINSKY SHAWN &CINDY 600446151370301 Withdrawal of water Domestic 71.00 S24 T001S R014W S JACKINSKY GARY 600406151381001 Withdrawal of water Domestic 64.00 S26 T001 S R014W S KVASNIKOFF JACK 600426151385101 Withdrawal of water Domestic 131.00 S26 T001S R014W S WIMMER BILL 600349151385501 Withdrawal of water Domestic 146.00 S26 T001S R014W S BANTA ELMER 600343151384901 Withdrawal of water Domestic 153.00 S26 T001 S R014W S BANTA BILL 600318151391501 Withdrawal of water Domestic 106.00 S27 T001S R014W S LEMAN NICK 600246151395501 Withdrawal of water Commercial 20.00 S34 T001S R014W S INLET VIEW BAR CAFE 600236151394701 Withdrawal of water Domestic 24.00 S34 T001S R014W S HERMAN CLARENCE 600258151394101 Test Unused 30.00 S34 T001S R014W S USGS NINILCHK 600235151393101 Withdrawal of water Domestic 50.00 S34 T001S R014W S SENIOR CITIZENS BUILDING 600238151395101 Withdrawal of water Domestic 60.00 S34 T001 S R014W S KOPCZYNSKI B 600228151403001 Withdrawal of water Other 67.00 S34 T001S R014W S T.J. STORE NINILCHK 600257151395001 Withdrawal of water Domestic 69.00 S34 T001S R014W S KVORNSKIEFF DEAN 600250151393101 Withdrawal of water Domestic 70.00 S34 T001 S R014W S COVEY ROGER 600237151402502 Withdrawal of water Institutional 80.00 S34 T001S R014W S NINILCHIK SCHOOL 600225151392701 Withdrawal of water Domestic 83.00 S34 T001S R014W S PHILLIPS ARNOLD R 600235151401301 Withdrawal of water Institutional 95.00 S34 T001S R014W S NINILCHIK NATIVE ASSN 600225151392601 Withdrawal of water Domestic 106.00 S34 T001S R014W S TSCHOEPL WENTSEL 600300151400901 Withdrawal of water Commercial 121.00 S34 T001S R014W S BERMAN PACK. CO 600259151394501 Withdrawal of water Public supply 125.00 S34 T001S R014W S NINILCHIK CITY OF 600251151400701 Withdrawal of water Public supply 201.00 S34 T001S R014W S AK DNR NINILCHK 600238151401501 Withdrawal of water Institutional 280.00 S34 T001S R014W S ADH NINILCHK 600237151402501 Withdrawal of water Institutional 292.00 S34 T001S R014W S NINILCHIK SCHOOL 600312151390001 Withdrawal of water Domestic 35.00 S35 T001S R014W S COOPER NICK 600240151384601 Withdrawal of water Domestic 50.00 S35 T001S R014W S PASCO JEFF 600234151384001 Withdrawal of water Domestic 70.00 S35 T001S R014W S HENDERSON 600316151384001 Withdrawal of water Domestic 72.30 S35 T001 S R014W S ENCELEWSKI RICHARD 600226151385601 Withdrawal of water Domestic 97.00 S35 T001S R014W S KINGSLY COLVIS 600230151384401 Withdrawal of water Domestic 157.00 S35 T001S R014W S BYRNE GERALD T 1 Wate Its Within 10 -Miles of the NNA #1 • • Dee k Unit APPENDIX B Kenai eninsula Borough, Alaska 23- Jun -04 WELL DEPTH TOWNSHIP & STATION ID SITE USE H2O_USE1 (feet) SECTION RANGE OWNER 600256151400401 Withdrawal of water Domestic 180.00 S35 T001 S R014W S AK DIV PKS NINILCHICK 600145151352501 Withdrawal of water Domestic 82.00 S06 T002S R013W S MAZE ART 600147151352401 Withdrawal of water Domestic 118.00 S06 T002S R013W S MAZE ARTHUR 600044151320701 Withdrawal of water Domestic 45.00 S09 T002S R013W S CLARK KENNETH 600039151320101 Withdrawal of water Domestic 45.00 S16 T002S R013W S HANSON PAULINE 600219151361901 Withdrawal of water Domestic 38.00 S01 T002S R014W S POTTER RONALD 600140151372401 Withdrawal of water Domestic 43.00 SO2 T002S R014W S CONSTANCE AL 600148151384701 Withdrawal of water Domestic 50.00 SO2 T002S R014W S COVEY ROGER 600142151372301 Withdrawal of water Domestic 58.00 SO2 T002S R014W S MCHONE DON • 600141151374801 Withdrawal of water Domestic 71.00 SO2 T002S R014W S WHITMORE ELMER 600142151374201 Withdrawal of water Domestic 80.00 SO2 T002S R014W S WILCOCK JACK 600145151385301 Withdrawal of water Domestic 85.00 SO2 T002S R014W S COREY 600139151382801 Withdrawal of water Domestic 90.00 SO2 T002S R014W S MCHONE JACK 600204151373701 Withdrawal of water Domestic 162.00 SO2 T002S R014W S DEMMICK 600208151403501 Withdrawal of water Domestic 25.00 S03 T0025 R014W S KELLY VICTOR 600215151390501 Withdrawal of water Domestic 40.00 S03 T002S R014W S BEYER PAT 600204151393601 Withdrawal of water Domestic 45.00 S03 T002S R014W S HASTINGS RODLEY 600222151391902Test Unused 50.00 S03 T002S R014W S USGS NINILCHIK 600220151394601 Withdrawal of water Domestic 52.00 S03 T002S R014W S KVASNIKOFF DEAN 600220151393001 Withdrawal of water Domestic 73.00 S03 T002S R014W S CHENIER ROBERT 600222151391901 Test Unused 181.00 S03 T002S R014W S USGS NINILCHIK 600201151412001 Withdrawal of water Domestic 58.00 SO4 T002S R014W S STEIK ALVIN 600145151404301 Withdrawal of water Domestic 86.00 SO4 T002S R014W S LUCASON ROBERT 600211151413001 Withdrawal of water Domestic 195.00 SO4 T002S R014W S PORTER CLIFFORD &BETTY 600203151413001 Withdrawal of water Domestic 198.00 SO4 T002S R014W S STEIK MIKE 600202151414601 Withdrawal of water Domestic 215.00 SO4 T002S R014W S MOE STEVE 600132151415301 Withdrawal of water Domestic 64.70 S09 T002S R014W S MORSE 600118151411201 Withdrawal of water Domestic 210.00 S09 T002S R014W S KOBS MURIEL #. 600051151403701 Withdrawal of water Domestic 32.00 S10 T002S R014W S PICASO TOM 600107151402501 Withdrawal of water Domestic 36.00 S10 T002S R014W S MULLER GENE 600111151375201 Withdrawal of water Domestic 42.00 S11 T002S R014W S GROESSE PAUL 600034151393201 Withdrawal of water Domestic 74.00 S15 T002S R014W S GARROUTTE GARRY 595945151425601 Withdrawal of water Domestic 83.00 S20 T002S R014W S MILLET DICK 595934151425701 Withdrawal of water Domestic 85.00 S20 T002S R014W S NAYLOR DAVID R 595947151430301 Withdrawal of water Domestic 97.00 S20 T002S R014W S GARRESTON DEVELOPMENT INC 595929151431601 Withdrawal of water Domestic 111.00 S20 T002S R014W S VALAER GENE 595818151425601 Withdrawal of water Domestic 22.00 S29 T002S R014W S BUTLER DON 595833151425601 Withdrawal of water Domestic 26.00 S29 T002S R014W S MCCUNE EMMA 595842151425601 Withdrawal of water Domestic 95.00 S29 T002S R014W S MCGOWAN 595714151423201 Withdrawal of water Domestic 30.00 S32 T002S R014W S WENZEL WALTER 595725151430101 Unused Unused 30.00 S32 T002S R014W S BELL DENNY 595731151420901 Withdrawal of water Domestic 58.00 S33 T002S R014W S WESTERGAARD JAMES 600221 1 51 394301 Withdrawal of water Domestic 160.00 S03 T003S R014W S PHILLIPS ARNOLD R 2
