18424-AG-CE-61 Page 1 of 2

18424-AG-CE-61

Question:

34. Refer to page 25, lines 13-18, of Ms. Palkovich’s direct testimony. Please:

a. Explain why no significant expense was incurred in 2016 and 2017 with regard toMAOP documentation given that work on this project began in 2012.

b. Provide MAOP program work plans for 2018 and 2019.c. Provide supporting detail for the forecasted expenses in 2018, 2019 and projected test

year in Excel showing how the forecasted costs were determined.

Response:

a. Initial verification work began in 2012 as required by the Pipeline Safety, RegulatoryCertainty, and Job Creation Act of 2011. The Company anticipated additionalguidance as indicated in Advisory Bulletin12-06 prior to beginning the next portionof verification analysis. The guidance that was indicated in the Safety of GasTransmission and Gathering Pipelines – Notice of Proposed Rulemaking (NPRM),issued in 2016, resulted in the Company’s decision to perform a detailed engineeringanalysis to ensure traceable, verifiable and complete records in accordance withAdvisory Bulletin 12-06. To complete this effort, in 2017 Consumers embarked inthe planning of a program that included a detailed engineering analysis for thetransmission system that will include upgrading the documentation from a historicalperspective to new information management standards.

b. See the table below which shows the annual O&M expense in 2018 and 2019 for theMAOP program broken down by project. The test year O&M is calculated as 50% of2018 and 50% of 2019. Project timing will be dependent upon the outage schedulefor each pipeline which are typically determined in the first quarter of the year inwhich the projects will commence.

18424-AG-CE-61Page 1 of 2

42400129

Case No.: U-18424 Witness: C. Creisher

Exhibit: S-11.11 Page: 1 of 5

c. See the attachments labeled 18424-AG-CE-61c.

___________________________ Mary P. Palkovich December 12, 2017

Gas Engineering & Supply Department


42400130



18424-AG-CE-61c Attachment page 1 of 3Project ID: 0 Description:

Construction Site: T/R/S: Estimate Type: Conceptual

Estimator's Note(s)/Assumptions:1)2)3)4)

0.00% EstimateSAP Order Direct Cost Contingency% Contingency$

T&S GCON Materials: 5866000 Blowdown: $1,000 0.00% $0 $1,000

5101500 Cathodic: $0 0.00% $0 $05101500 Civil: $0 0.00% $0 $0

5101500 Mechanical: $10,000 0.00% $0 $10,0005101500 Electrical: $0 0.00% $0 $0

5101500 I&C: $0 0.00% $0 $0 $102,000 Stock/NonStock Material $$5101500 Minor Matls/Small Tools: $0 0.00% $0 $0 1.00% Materials

5101700 NonStock Mtls: $92,000 0.00% $0 $92,000 $10,000 Stock Material $$5101500 PCN Mtls: $0 $0 0.00% Indirect Materials Loading (Stock Mtls)

C6075 Gas Indirect Mtls Lbr: $0 $0 0.00% C6075 Stock MaterialsC6080 Gas Indirect Mtls NLbr: $0 $0 0.00% C6080 Stock Materials

C1030 MDC Labor: $0 $0 0.00% MDC Stock NonStock MaterialsC1040 MDC Non Labor: $0 $0 0.00% MDC Stock NonStock Materials

C1050 CSC Labor: $0 $0 0.00% CSC Stock NonStock MaterialsC1060 CSC Non Labor: $0 $0 0.00% CSC Stock NonStock MaterialsC1061 T&S Stores Lbr: $6,000 $6,000 5.00% T&S Stores Stock NonStock Materials

C1062 T&S Stores NLbr: $2,000 $2,000 2.00% T&S Stores Stock NonStock Materials$0$0

5503500 Contractor Cost (Outside Services): $1,850,000 0.00% $0 $1,850,0005508000 Contractor Cost-Other: $215,000 0.00% $0 $215,000

A1000 OM&C Direct Lbr: $14,000 0.00% $0 $14,000 $14,000 OM&C Labor $$A3000 Non Exempt Direct Lbr: $0 0.00% $0 $0 15.55% Vehicle Loading

C1095 Fleet Serviceslbr: $1,000 $1,000 28.00% OM&C LaborC8085 Fleet ServicesNlbr: $2,000 $2,000 72.00% OM&C Labor

C 1096 NonPremise: $4,000 $4,000 25.09% NonPremise Loading OM&C Labor

Support Services:5380000 Lab Services Lbr: $22,000 0.00% $0 $22,000

5390000 Lab Services NonLbr: $6,000 $6,000Legal: $0 0.00% $0 $0

M1081 Environmental: $0 0.00% $0 $0M1034 Real Estate: $60,000 0.00% $0 $60,000

A3500 Engineeering: $0 0.00% $0 $05210000 Fees and Permits: $7,000 0.00% $0 $7,000 $2,161,000 CECO & Contractor Labor $$

5201200 General Travel-Other: $0 0.00% $0 $0 0.00% Capital Non Asset LoadingC1097 Capital Non Asset Lbr: $0 $0 0.00% CECO & Contractor Labor

C8087 Capital Non Asset NLbr: $0 $0 0.00% CECO & Contractor Labor

A1000 PCN OM&C Lbr: $0 $05503500 PCN Contractor Lbr: $0 $0 $2,292,000 Verify Total Calcs

COR Total Direct Cost $2,292,000 $0 $2,292,000 0.00% Cont % of Direct $$

NVL1020-1-16 NVLCS-S Lyon-Whtmr Lk Tst

Scope of Work: Hydrotest the 16" Line installation. This will require a blowdown of the 16" line. The 16" line has launchers/receivers at both ends of the line. Currently the 16" line will also have to be excavated, cut and a temporary launcher/receiver installed between the launchers/receivers and the isolation valves to allow for testing and dewatering. The Line installation area will be isolated, cleaned, filled with water, tested for 8 hours and dewatered. The 16" temporary launchers/receivers will be removed, pretested 16" tie-in pipe will be installed and tie-in welds x-rayed at both sites. The tie-in pipe will be coated and wrapped and the entire area backfilled at both sites.

5.407 miles





Estimator's Note(s)/Assumptions:1) .062+5.850=5.912 miles.2)3)4)



5101500 Cathodic: $0 0.00% $0 $05101500 Civil: $0 0.00% $0 $0














M1081 Environmental: $0 0.00% $0 $0M1034 Real Estate: $40,000 0.00% $0 $40,000






NVL1070-2-16 Shldn Rd CG Line Test

Scope of Work: Hydrotest the 16" Line installation. This will require a blowdown of the 16" line. The 16" line has launchers/receivers at both ends of the line. Currently the 16" line will also have to be excavated, cut and a temporary launcher/receiver installed between the launchers/receivers and the isolation valves to allow for testing and dewatering. The Line installation area will be isolated, cleaned, filled with water, tested for 8 hours and dewatered. The 16" temporary launchers/receivers will be removed, pretested 16" tie-in pipe will be installed and tie-in welds x-rayed at both sites. The tie-in pipe will be coated and wrapped and the entire area backfilled at both sites.





Estimator's Note(s)/Assumptions:1)2)3)4)



5101500 Cathodic: $0 0.00% $0 $05101500 Civil: $0 0.00% $0 $0














M1081 Environmental: $1,000 0.00% $0 $1,000M1034 Real Estate: $120,000 0.00% $0 $120,000






Use 16" pig test headers and cleaning pig from 1020-1-16

NVL-1600-2-16 NVLCS-Coolidge CG Tst

Scope of Work: Hydrotest the 16" Line installation. This will require a blowdown of the 16" line. The 16" line has launchers/receivers at both ends of the line. Currently the 16" line will also have to be excavated, cut and a temporary launcher/receiver installed at some point west of 12 Mile and Haggerty Rd Valve Site and around West Wayne City Gate to allow for continuity of service to customers off the 16" Line #1600 and for testing and dewatering purposes. The Line installation areas will be isolated, cleaned, filled with water, tested for 8 hours and dewatered. The 16" temporary launchers/receivers will be removed, pretested 16" tie-in pipe will be installed and tie-in welds x-rayed at both sites. The tie-in pipe will be coated and wrapped and the entire area backfilled at both sites. 8" Lahser lateral - install pig test headers, clean pipe, hydrotest pipe for 8 hours, clean pipe, remove pig test headers and tie line back in. Restore site. 1/4 mile.

16" 21.18 miles8" 1,346'



18424-AG-CE-69

Question:

42. Refer to page 47, lines 8-26, and page 48, lines 1-3, of Ms. Palkovich’s direct testimony.Please:

a. Explain how the Company was able to base the MAOP cost projections on previouslycompleted work orders of similar magnitude and requirements, when it seems therewere no capital expenditures for such projects in the historical periods.

b. Identify specifically the projects that were used as a basis to project costs for theforecasted periods. Please include the magnitude of those projects and the year thatthey were completed.

c. Provide the capital expenditures by month from start to completion related to each ofthe projects identified on lines 9-12, lines 19-26, and page 48, lines 1-3, along withany other projects that total to the costs presented in Exhibit A-57 (MPP-10), page 1,lines 12-13. Provide this information in Excel.

d. Provide the detailed work plans with timelines related to the projects identified in thepreceding question in subpart (c) that equal or exceed $2 million.

e. Explain why the Company believes its verification program will discover complianceproblems in the identified projects. What is the basis for this belief?

f. If the Company is aware of known deficiencies in complying with MAOPrequirements, explain when those deficiencies were discovered for each project andwhy they were not remedied earlier.

g. For each of the cases where a discrepancy has been identified between the MAOP andthe Company’s records that requires a remediation, explain the cause of thediscrepancy and the O&M or capital cost to resolve that discrepancy.

h. Explain what the problems are with the Line 1200B, Line 1300, the Lasher lateral andLine 3070 that require MAOP remediation. Explain what type of remediation will bedone.

i. Explain why the Tecumseh City gate project is an MAOP project.j. Explain why the costs to remediate MAOP problems or discrepancies with Company

records should be included in rate base and the revenue requirement when theCompany should have been compliant at the time the facilities were originally built.

Response:

a. The type of work to be performed in the MAOP Pipeline program is pipe replacementand remediation that the Company conducts as part of many existing programsincluding Pipeline Integrity Transmission, Compliance Base Pipeline, AssetRelocations etc.

b. The reference in my direct testimony was concerning the city gate projects that arepart of this program. The most recent data we have for estimating these projectswould come from the city gates installed as part of the Saginaw Trail Pipeline project.These city gates which were installed in 2017 are the Clio and Bridgeport city gates.These projects were used as a basis for estimating the project expenditures withadditional costs for real estate and distribution pipeline installation. These projects


42400132



have costs for retirement and distribution augmentation, which makes them the best reference for the city gate projects included in this program as the scope is the most similar. These were completed in 2017 at an excess of three million dollars each.

c. The attachment labeled 18424-AG-CE-69c contains the requested information. The2019 projects will be primarily identified as part of the Engineering Analysis and isbased upon the 2018 project expenditures and list of segments falling under theMAOP Pipeline program which was compiled as part of the ongoing analysis. TheEngineering analysis currently under way on the 111 miles of transmission pipelinefor which the Company must ensure compliance and public safety will determine theprioritized projects for 2019 and beyond.

d. The time frame for the projects will be between March and November and will bedependent upon the outage schedule which will be determined by the Gas Controldepartment in the first quarter of 2018 for 2018 projects and first quarter of 2019 for2019 projects.

e. The basis is the preliminary results of the Verification work performed starting in2012.

f. MAOP Compliance Pipeline Program involves MAOP verification and remediationof the Company’s transmission pipeline, including TOD. This work began in 2012,in response to the Pipeline Safety, Regulatory Certainty, and Job Creation Act of2011, which required PHMSA to direct each owner or operator of a gas transmissionpipeline and associated features to provide verification that their records accuratelyreflect a pipeline’s MOAP. This will assure compliance with overall pipeline recordsrequirements and increasing customer confidence in public safety. The program is notin response to known deficiencies as described in this interrogatory.

g. See part (h) below for capital projects. The three O&M projects identified in theresponse to 18424-AG-CE-61 only have a pre-July 1, 1965 pressure test. Theprojects in this program are as a result of the analysis and will determine where workis required to meet the new traceable, verifiable, and complete guidance provided inAdvisory Bulletin 12-06, while also upgrading the documentation from a historicalperspective to new information management standards. Once locations not meetingthe criteria established by the new advisory bulletin are determined, the Companywill address these pipeline segments through a risk-based evaluation, resulting ineither hydrotesting, which is part of the MAOP O&M Program, or replacement. TheEngineering analysis currently under way on the 111 miles of transmission pipelinefor which the Company must ensure compliance and public safety will determine theprioritized projects for 2019 and beyond.

h. Line 1200B – has an elbow that is not commensurate with the current class and needsto be replaced. Line 1300 – has four elbows for which design information has notbeen identified. These will be replaced. Lahser line only has a pre-July 1, 1965pressure test and design information is lacking. Scheduled for replacement.Line 3070 only has a pre-July 1, 1965 pressure test and design information is suspect.Scheduled for replacement.

i. The Tecumseh city gate rebuild and associate work falls into the MAOP M&Rcategory as the investment will ensure compliance with MAOP regulations on the3060 line by retiring it. Distribution facilities will be installed downstream of therelocated city gate


42400133



j. Besides the enhancements to safety and deliverability provided by these investments,the expenditures are also in response to the fact that PHMSA has revised therecording requirements for pipelines by introducing the descriptions of traceable,verifiable and complete in Advisory Bulletin 12-06.




42400134



18424-AG-CE-69c

$(000)MAOP Compliance Pipeline2018 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total

Line 1200B - 36" Fitting Replacements - 2 elbows 20 18 12 37 70 137 123 152 96 106 101 73 947 Line 1300 - 247' of 12" Pipe Replacement - Station 730+07 to 732+54 11 9 6 20 37 72 64 79 50 55 53 38 494 Line 1300 - 2,837' of 12" Pipe Replacement - Station 1158+04 to 1186+41 21 19 13 39 73 142 127 157 99 109 104 75 976 Lahser Lateral - 1,395' of 8" Pipe Replacement - Station 0+0 to 13+95 103 92 63 191 359 700 629 776 487 541 513 373 4,827

MAOP Compliance Pipeline - 2019 Jan Feb Mar Apr May Jun Total

Line 1200B - 36" Fitting Replacements - 2 elbows 3 2 1 0 0 0 6 Line 1300 - 247' of 12" Pipe Replacement - Station 730+07 to 732+54 3 2 1 0 0 0 6 Line 1300 - 2,837' of 12" Pipe Replacement - Station 1158+04 to 1186+41 72 37 20 11 9 6 154 Lahser Lateral - 1,395' of 8" Pipe Replacement - Station 0+0 to 13+95 15 8 4 2 2 1 32 Line 3070 - Blissfield - 2.4 Miles of 4" Pipe Replacement 42 37 25 78 146 284 612

MAOP Compliance Measurement & Regulation Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Total

2018Tecumseh city gate / retirement of line 3060 114 101 69 211 397 774 695 858 539 598 567 413 5,336 Williamston city gate 85 75 51 157 295 575 517 637 400 444 421 307 3,965 1012/1017/1014 and new HP/HP station 68 61 41 126 237 463 416 513 322 358 339 247 3,190 Novi Wixom city gate 31 28 19 57 108 210 189 233 146 163 154 112 1,450

13,941



Notice: This report is required by 49 CFR Part 191. Failure to report may result in a civil penalty not to exceed $100,000 for each violation Form Approvedfor each day the violation continues up to a maximum of $1,000,000 as provided in 49 USC 60122. OMB No. 2137-0522

Expires: 01/13/2014

Form PHMSA F 7100.2-1 (Rev. 12-2012) Pg. 1 of 11Reproduction of this form is permitted.

U.S. Department of Transportation

Pipeline and Hazardous Materials

Safety Administration

ANNUAL REPORT FOR CALENDAR YEAR 2012NATURAL OR OTHER GAS TRANSMISSION and

GATHERING SYSTEMS

Report Submission

TypeINITIAL

Date Submitted 6/14/2013

A federal agency may not conduct or sponsor, and a person is not required to respond to, nor shall a person be subject to a penalty for failure to comply with a collection of information subject to the requirements of the Paperwork Reduction Act unless that collection of information displays a current valid OMB Control Number. The OMB Control Number for this information collection is 2137-0522. Public reporting for this collection of information is estimated to be approximately 22 hours per response, including the time for reviewing instructions, gathering the data needed, and completing and reviewing the collection of information. All responses to this collection of information are mandatory. Send comments regarding this burden estimate or any other aspect of this collection of information, including suggestions for reducing this burden to: Information Collection

Clearance Officer, PHMSA, Office of Pipeline Safety (PHP-30) 1200 New Jersey Avenue, SE, Washington, D.C. 20590.

Important: Please read the separate instructions for completing this form before you begin.

PART A - OPERATOR INFORMATION DOT USE ONLY 20130900 - 26961

1. OPERATOR'S 5 DIGIT IDENTIFICATION NUMBER (OPID)

2748

2. NAME OF OPERATOR:

CONSUMERS ENERGY CO IF SUBSIDIARY, NAME OF PARENT:

CMS Energy

3. RESERVED 4. HEADQUARTERS ADDRESS:

ONE ENERGY PLAZAStreet Address

JACKSONCity

State: MI Zip Code: 49201

5. THIS REPORT PERTAINS TO THE FOLLOWING COMMODITY GROUP: (Select Commodity Group based on the predominant gas carried and complete the report for that Commodity Group. File a separate report for each Commodity Group included in this OPID.)

Natural Gas

6. CHARACTERIZE THE PIPELINES AND/OR PIPELINE FACILITIES COVERED BY THIS OPID AND COMMODITY GROUP WITH RESPECT TO COMPLIANCE WITH PHMSA'S INTEGRITY MANAGEMENT PROGRAM REGULATIONS (49 CFR 192 Subpart O).

7. FOR THE DESIGNATED "COMMODITY GROUP", THE PIPELINES AND/OR PIPELINE FACILITIES INCLUDED WITHIN THIS OPID ARE:(Select one or both)

INTERstate pipeline – List all of the States and OSC portions in which INTERstate pipelines and/or pipeline facilities included under this OPID exist. etc.

INTRAstate pipeline – List all of the States in which INTRAstate pipelines and or pipelinefacilities included under this OPID exist. MICHIGAN etc.

8. RESERVED




Expires: 01/13/2014


For the designated Commodity Group, complete PARTs B, C, D, and E one time for all pipelines and/or pipeline facilities – both INTERstate and INTRAstate - included within this OPID.

PART B – TRANSMISSION PIPELINE HCA MILES

Number of HCA Miles

Onshore 304.8

Offshore 0

Total Miles 304.8

PART C - VOLUME TRANSPORTED IN TRANSMISSION PIPELINES (ONLY) IN MILLION SCF PER YEAR (excludesTransmission lines of Gas Distribution systems)

Check this box and do not complete PART C if this report only includes gathering pipelines or transmission lines of gas distribution systems.

Onshore Offshore

Natural Gas 321364

Propane Gas

Synthetic Gas

Hydrogen Gas

Landfill Gas

Other Gas - Name:

PART D - MILES OF STEEL PIPE BY CORROSION PROTECTION

Steel Cathodicallyprotected

Steel Cathodically unprotected

Bare Coated Bare Coated Cast Iron Wrought Iron Plastic Composite1 Other Total Miles

TransmissionOnshore 43 2371.7 0 7.1 0 0 0 0 0 2421.8

Offshore 0 0 0 0 0 0 0 0 0 0

Subtotal Transmission

43 2371.7 0 7.1 0 0 0 0 0 2421.8

GatheringOnshore Type A 0 0 0 0 0 0 0 0 0 0

Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0 0

Subtotal Gathering

0 0 0 0 0 0 0 0 0 0

Total Miles 43 2371.7 0 7.1 0 0 0 0 0 2421.8

1Use of Composite pipe requires a PHMSA Special Permit or waiver from a State

PART E – Reserved. Data for Part E has been merged into Part D for 2010 and 2011 Annual Reports.




Expires: 01/13/2014


For the designated Commodity Group, complete PARTs F and G one time for all INTERstate pipelinesand/or pipeline facilities included within this OPID and multiple times as needed for the designatedCommodity Group for each State in which INTRAstate pipelines and/or pipeline facilities included withinthis OPID exist. Each time these sections are completed, designate the State to which the data appliesfor INTRAstate pipelines and/or pipeline facilities, or that it applies to all INTERstate pipelines includedwithin this Commodity Group and OPID.

PARTs F and G

The data reported in these PARTs for the designated Commodity Group, complete PARTs F and G one time for all INTERstate pipelines and/or pipeline facilities included within this OPID and multiple times as needed for the designated Commodity Group for each State in which INTRAstate pipelines and/or pipeline facilities included within this OPID exist. Part F "WITHIN AN HCA SEGMENT" data and Part G may be completed only if HCA Miles in Part L is greater than zero applies to: (select only one)

PART F - INTEGRITY INSPECTIONS CONDUCTED AND ACTIONS TAKEN BASED ON INSPECTION

INTRASTATE pipelines/pipeline facilities MICHIGAN

1. MILEAGE INSPECTED IN CALENDAR YEAR USING THE FOLLOWING IN-LINE INSPECTION (ILI) TOOLS

a. Corrosion or metal loss tools 63.4

b. Dent or deformation tools 186.77

c. Crack or long seam defect detection tools 61.48

d. Any other internal inspection tools, specify other tools: 0

1. Internal Inspection Tools - Other 0

e. Total tool mileage inspected in calendar year using in-line inspection tools. (Lines a + b + c + d ) 311.65

2. ACTIONS TAKEN IN CALENDAR YEAR BASED ON IN-LINE INSPECTIONS

a. Based on ILI data, total number of anomalies excavated in calendar year because they met the operator's criteria for excavation. 1141

b. Total number of anomalies repaired in calendar year that were identified by ILI based on the operator's criteria, both within an HCA Segment and outside of an HCA Segment. 1074

c. Total number of conditions repaired WITHIN AN HCA SEGMENT meeting the definition of: 9

1. "Immediate repair conditions" [192.933(d)(1)] 4

2. "One-year conditions" [192.933(d)(2)] 0

3. "Monitored conditions" [192.933(d)(3)] 0

4. Other "Scheduled conditions" [192.933(c)] 5

3. MILEAGE INSPECTED AND ACTIONS TAKEN IN CALENDAR YEAR BASED ON PRESSURE TESTING

a. Total mileage inspected by pressure testing in calendar year. 0

b. Total number of pressure test failures (ruptures and leaks) repaired in calendar year, both within an HCA Segment and outside of an HCA Segment.

0

c. Total number of pressure test ruptures (complete failure of pipe wall) repaired in calendar year WITHIN AN HCA SEGMENT.

0

d. Total number of pressure test leaks (less than complete wall failure but including escape of test medium) repaired in calendar year WITHIN AN HCA SEGMENT. 0

4. MILEAGE INSPECTED AND ACTIONS TAKEN IN CALENDAR YEAR BASED ON DA (Direct Assessment methods)

a. Total mileage inspected by each DA method in calendar year. 27.26

1. ECDA 12.83

2. ICDA 14.43

3. SCCDA 0

b. Total number of anomalies identified by each DA method and repaired in calendar year based on the operator's criteria, both within an HCA Segment and outside of an HCA Segment. 0

1. ECDA 0




Expires: 01/13/2014


2. ICDA 0

3. SCCDA 0

c. Total number of conditions repaired in calendar year WITHIN AN HCA SEGMENT meeting the definition of: 0





5. MILEAGE INSPECTED AND ACTIONS TAKEN IN CALENDAR YEAR BASED ON OTHER INSPECTION TECHNIQUES

a. Total mileage inspected by inspection techniques other than those listed above in calendar year. 0

1.Other Inspection Techniques 0

b. Total number of anomalies identified by other inspection techniques and repaired in calendar year based on the operator's criteria, both within an HCA Segment and outside of an HCA Segment. 0





4. Other "Scheduled conditions" [192.933©] 0

6. TOTAL MILEAGE INSPECTED (ALL METHODS) AND ACTIONS TAKEN IN CALENDAR YEAR

a. Total mileage inspected in calendar year. (Lines 1.e + 3.a + 4.a.1 + 4.a.2 + 4.a.3 + 5.a) 338.91

b. Total number of anomalies repaired in calendar year both within an HCA Segment and outside of an HCA Segment. (Lines 2.b + 3.b + 4.b.1 + 4.b.2 + 4.b.3 + 5.b) 1074

c. Total number of conditions repaired in calendar year WITHIN AN HCA SEGMENT. (Lines 2.c.1 + 2.c.2 + 2.c.3 + 2.c.4 + 3.c + 3.d + 4.c.1 + 4.c.2 + 4.c.3 + 4.c.4 + 5.c.1 + 5.c.2 + 5.c.3 + 5.c.4) 9

d. Eliminated by Replacement 0

e. Eliminated by Abandonment 0

PART G– MILES OF BASELINE ASSESSMENTS AND REASSESSMENTS COMPLETED IN CALENDAR YEAR (HCA Segment miles ONLY)

a. Baseline assessment miles completed during the calendar year. 14.63

b. Reassessment miles completed during the calendar year. 13.327

c. Total assessment and reassessment miles completed during the calendar year. 27.957




Expires: 01/13/2014


For the designated Commodity Group, complete PARTs H, I, J, K, L, M, P Q and R covering INTERstatepipelines and/or pipeline facilities for each State in which INTERstate systems exist within this OPID andagain covering INTRAstate pipelines and/or pipeline facilities for each State in which INTRAstate systemsexist within this OPID.

PARTs H, I, J, K, L, M, P, Q, and R

The data reported in these PARTs applies to: (select only one)


PART H - MILES OF TRANSMISSION PIPE BY NOMINAL PIPE SIZE (NPS)

Onshore

NPS 4or less 6 8 10 12 14 16 18 20

132.2 40 272 187.7 505.5 46 157.7 30.2 185.3

22 24 26 28 30 32 34 36 38

104.8 182.4 380 0 15.5 0 0 182.5 0

40 42 44 46 48 52 5658 and

over

0 0 0 0 0 0 0 0

Additional Sizes and Miles (Size – Miles;): 0 - 0; 0 - 0; 0 - 0; 0 - 0; 0 - 0; 0 - 0; 0 - 0; 0 - 0; 0 - 0;

2421.8 Total Miles of Onshore Pipe – Transmission

Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and

over

Additional Sizes and Miles (Size – Miles;): - ; - ; - ; - ; - ; - ; - ; - ; - ;

Total Miles of Offshore Pipe – Transmission

PART I - MILES OF GATHERING PIPE BY NOMINAL PIPE SIZE (NPS)

Onshore Type A

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38




Expires: 01/13/2014


40 42 44 46 48 52 5658 and over

Additional Sizes and Miles (Size – Miles;):

Total Miles of Onshore Type A Pipe – Gathering

Onshore Type B

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 56 58 and over


Total Miles of Onshore Type B Pipe – Gathering

Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and over


Total Miles of Offshore Pipe – Gathering

PART J – MILES OF PIPE BY DECADE INSTALLED

Decade Pipe Installed

Unknown Pre-40 1940 - 1949 1950 - 1959 1960 - 1969 1970 - 1979

Transmission

Onshore 1 19 347.5 621.3 905.2 267.4

Offshore 0

Subtotal Transmission 1 19 347.5 621.3 905.2 267.4

Gathering

Onshore Type A 0

Onshore Type B 0

Offshore 0

Subtotal Gathering 0

Total Miles 1 19 347.5 621.3 905.2 267.4


1980 - 1989 1990 - 1999 2000 - 2009 2010 - 2019 Total Miles

Transmission

Onshore 39.8 106.5 86.3 27.8 2421.8

Offshore 0

Subtotal Transmission 39.8 106.5 86.3 27.8 2421.8




Expires: 01/13/2014


Gathering

Onshore Type A 0

Onshore Type B 0

Offshore 0


Total Miles 39.8 106.5 86.3 27.8 2421.8

PART K- MILES OF TRANSMISSION PIPE BY SPECIFIED MINIMUM YIELD STRENGTH

ONSHORECLASS LOCATION Total Miles

Class I Class 2 Class 3 Class 4

Steel pipe Less than 20% SMYS 47.3 7.4 1.4 0 56.1

Steel pipe Greater than or equal to 20% SMYS but less than 30% SMYS

138.9 171.8 287.2 1 598.9

Steel pipe Greater than or equal to 30% SMYS but less than or equal to 40% SMYS

71.9 13.7 59.3 .6 145.5

Steel pipe Greater than 40% SMYS but less than or equal to 50% SMYS

176.5 74.2 166.2 1.5 418.4


467.5 253.6 105.6 0 826.7


282.3 82.1 11.8 0 376.2


0 0 0 0 0

Steel pipe Greater than 80% SMYS 0 0 0 0 0

Steel pipe Unknown percent of SMYS 0 0 0 0 0

All Non-Steel pipe 0 0 0 0 0

Onshore Totals 1184.4 602.8 631.5 3.1 2421.8

OFFSHORE Class I

Less than or equal to 50% SMYS

Greater than 50% SMYS but less than or equal to 72% SMYS

Steel pipe Greater than 72% SMYS

Steel Pipe Unknown percent of SMYS

All non-steel pipe

Offshore Total

Total Miles 1184.4 2421.8

PART L - MILES OF PIPE BY CLASS LOCATIONClass Location Total

Class Location Miles

HCA Miles in the IMP ProgramClass I Class 2 Class 3 Class 4

TransmissionOnshore 1184.4 602.8 631.5 3.1 2421.8 304.8

Offshore 0 0 0 0





Expires: 01/13/2014


GatheringOnshore Type A

Onshore Type B

Offshore

Subtotal Gathering

Total Miles 1184.4 602.8 631.5 3.1 2421.8 304.8

PART M – FAILURES, LEAKS, AND REPAIRS

PART M1 – ALL LEAKS ELIMINATED/REPAIRED IN CALENDAR YEAR; INCIDENTS & FAILURES IN HCA SEGMENTS IN CALENDAR YEAR

Cause

Transmission Leaks, and Failures Gathering Leaks

Leaks Failures in HCA

Segments

Onshore Leaks Offshore Leaks

Onshore Leaks Offshore LeaksHCA Non-HCA HCA Non-HCA Type A Type B

External Corrosion 0 0 0 0 0

Internal Corrosion 0 0 0 0 0

Stress Corrosion Cracking 0 0 0 0 0Manufacturing 0 0 0 0 0Construction 0 0 0 0 0Equipment 1 8 0 0 0Incorrect Operations 0 1 0 0 0

Third Party Damage/Mechanical DamageExcavation Damage 0 1 0 0 0Previous Damage (due to Excavation Activity)

0 0 0 0 0

Vandalism (includes all Intentional Damage)

0 0 0 0 0

Weather Related/Other Outside ForceNatural Force Damage (all) 0 0 0 0 0Other Outside Force Damage (excluding Vandalism and all Intentional Damage)

0 0 0 0 0

Other 12 0 0 0

Total 1 22 0 0 0

PART M2 – KNOWN SYSTEM LEAKS AT END OF YEAR SCHEDULED FOR REPAIR

Transmission 15 Gathering 0

PART M3 – LEAKS ON FEDERAL LAND OR OCS REPAIRED OR SCHEDULED FOR REPAIR

Transmission Gathering

Onshore 0Onshore Type A

Onshore Type B

OCS 0 OCSSubtotal Transmission 0 Subtotal Gathering

Total 0




Expires: 01/13/2014


PART P - MILES OF PIPE BY MATERIAL AND CORROSION PROTECTION STATUS

Steel Cathodically protected


Bare Coated Bare Coated Cast Iron

WroughtIron Plastic Composite1 Other2 Total Miles

TransmissionOnshore 43 2371.7 0 7.1 0 0 0 0 0 2421.8

Offshore 0 0 0 0 0 0 0 0 0 0Subtotal

Transmission 43 2371.7 0 7.1 0 0 0 0 0 2421.8


Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0Subtotal Gathering 0 0 0 0 0 0 0 0 0 0

Total Miles 43 2371.7 0 7.1 0 0 0 0 0 2421.8

1Use of Composite pipe requires PHMSA Special Permit or waiver from a State2specify Other material(s):

Part Q - Gas Transmission Miles by §192.619 MAOP Determination Method(a)(1) Total

(a)(1) Incomplete

Records

(a)(2) Total

(a)(2) Incomplete

Records

(a)(3) Total

(a)(3) Incomplete

Records

(a)(4) Total

(a)(4) Incomplete

Records

(c)Total

(c)Incomplete

Records

(d)Total

(d) Incomplete

Records

Other1 Total

Other Incomplete

Records

Class 1 (in HCA) 6.42 0 .94 .94 .01 0 0 0 0 0 0 0 0 0

Class 1 (not in HCA)

1177.13

0 0 0 0 0 0

Class 2 (in HCA) 16.91 .13 2.18 1.53 .12 .05 0 0 0 0 0 0 0 0


583.49 0 0 0 0 0 0

Class 3 (in HCA) 143.31 21.59 35.08 25.06 89.36 8.34 0 0 0 0 0 0 7.38 0


131.38 19.74 58.32 36.9 143.21

17.28 0 0 0 0 0 0 23.46 0

Class 4 (in HCA) 1.57 .54 0 0 1.23 .5 0 0 0 0 0 .3 .3 0


0 0 0 0 0 0 0 0 0 0 0 0 0

Total 2060.21

42 96.52 64.43 233.93

26.17 0 0 0 0 0 0 31.14 0

Grand Total 2421.8

Sum of Total row for all "Incomplete Records" columns 132.6

1Specify Other method(s):

Class 1 (in HCA) Class 1 (not in HCA)


Class 3 (in HCA) 49 CFR 192.611; Change in class location: Confirmation or revision or maximum allowable

operating pressure.

Class 3 (not in HCA) 49 CFR 192.611; Change in class location: Confirmation or revision or maximum allowable

operating pressure.


operating pressure.





Expires: 01/13/2014


Part R – Gas Transmission Miles by Pressure Test (PT) Range and Internal Inspection

PT ≥ 1.25 MAOP 1.25 MAOP > PT ≥ 1.1 MAOP PT < 1.1 or No PT

Location

Miles Internal Inspection

ABLE

Miles Internal InspectionNOT ABLE

Miles InternalInspection

ABLE


Miles Internal Inspection ABLE


Class 1 in HCA 7.19 0 0 0 .08 .1

Class 2 in HCA 14.19 1.64 0 0 1.81 1.57

Class 3 in HCA 117.5 12.92 0 0 25.01 119.72

Class 4 in HCA 1.41 0 0 0 .38 1.39

in HCA subTotal 140.29 14.56 0 0 27.28 122.78

Class 1 not in HCA 755.43 164.33 0 0 72.94 184.43

Class 2 not in HCA 337.05 22.85 0 0 42.66 180.93

Class 3 not in HCA 117.57 12.69 0 0 46.36 179.75

Class 4 not in HCA 0 0 0 0 0 0

not in HCA subTotal 1210.05 199.87 0 0 161.96 545.11

Total 1350.34 214.43 0 0 189.24 667.89

PT ≥ 1.25 MAOP Total 1564.77 Total Miles Internal Inspection ABLE 1539.58

1.25 MAOP > PT ≥ 1.1 MAOP Total 0 Total Miles Internal Inspection NOT ABLE 882.32

PT < 1.1 or No PT Total 857.13 Grand Total 2421.9

Grand Total 2421.9




Expires: 01/13/2014


For the designated Commodity Group, complete PART N one time for all of the pipelines and/or pipeline facilities included within this OPID, and then also PART O if any gas transmission pipeline facilities included within this OPID have Part L HCA mile value greater than zero.

PART N - PREPARER SIGNATURE

Alan M. Chichester

Preparer's Name(type or print)

(989) 791-5841Telephone Number

Gas Regulatory Services Engineer

Preparer's Title

[email protected]

Preparer's E-mail Address

PART O - CERTIFYING SIGNATURE (applicable only to PARTs B, F, G, and M1)

Garrick J. Rochow

Senior Executive Officer's signature certifying the information in PARTs B, F, G, and M as required by49 U.S.C. 60109(f)


Garrick J. Rochow

Senior Executive Officer's name certifying the information in PARTs B, F, G, and M as required by49 U.S.C. 60109(f)

Vice President of Energy Delivery

Senior Executive Officer's title certifying the information in PARTs B, F, G, and M as required by49 U.S.C. 60109(f)

[email protected]

Senior Executive Officer's E-mail Address




Expires: 01/13/2014






GATHERING SYSTEMS

Initial Date Submitted 03/15/2014

Report Submission

TypeINITIAL

Date Submitted

A federal agency may not conduct or sponsor, and a person is not required to respond to, nor shall a person be subject to a penalty for failure to comply with a collection of information subject to the requirements of the Paperwork Reduction Act unless that collection of information displays a current valid OMB Control Number. The OMB Control Number for this information collection is 2137-0522. Public reporting for this collection of information is estimated to be approximately 22 hours per response, including the time for reviewing instructions, gathering the data needed, and completing and reviewing the collection of information. All responses to this collection of information are mandatory. Send comments regarding this burden estimate or any other aspect of this collection of information, including suggestions for reducing this burden to: Information Collection

Clearance Officer, PHMSA, Office of Pipeline Safety (PHP-30) 1200 New Jersey Avenue, SE, Washington, D.C. 20590.

Important: Please read the separate instructions for completing this form before you begin.



2748



CMS Energy



JACKSONCity



Natural Gas





8. RESERVED




Expires: 01/13/2014




Number of HCA Miles

Onshore 306.2

Offshore 0

Total Miles 306.2



Onshore Offshore

Natural Gas 334261

Propane Gas

Synthetic Gas

Hydrogen Gas

Landfill Gas

Other Gas - Name:





TransmissionOnshore 47.5 2381.6 0 3.6 0 0 0 0 0 2432.7

Offshore 0 0 0 0 0 0 0 0 0 0


47.5 2381.6 0 3.6 0 0 0 0 0 2432.7


Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0 0

Subtotal Gathering

0 0 0 0 0 0 0 0 0 0

Total Miles 47.5 2381.6 0 3.6 0 0 0 0 0 2432.7






Expires: 01/13/2014



PARTs F and G








d. Any other internal inspection tools, specify other tools: 0

1. Internal Inspection Tools - Other













0


0




1. ECDA 22.6

2. ICDA 25.19

3. SCCDA 0


1. ECDA 1




Expires: 01/13/2014


2. ICDA 1

3. SCCDA 0



















d. Eliminated by Replacement 0

e. Eliminated by Abandonment 16








Expires: 01/13/2014







Onshore

NPS 4or less 6 8 10 12 14 16 18 20

129.5 46.9 271.7 188.4 508.9 0 203.9 30.8 185.7

22 24 26 28 30 32 34 36 38

104.8 182.9 380.8 0 15.5 0 0 182.9 0

40 42 44 46 48 52 5658 and

over

0 0 0 0 0 0 0 0



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and

over




Onshore Type A

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38




Expires: 01/13/2014


40 42 44 46 48 52 5658 and over



Onshore Type B

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 56 58 and over



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and over





Unknown Pre-40 1940 - 1949 1950 - 1959 1960 - 1969 1970 - 1979

Transmission

Onshore 0 18.8 348 613.8 902 267.9

Offshore 0

Subtotal Transmission 0 18.8 348 613.8 902 267.9

Gathering

Onshore Type A 0

Onshore Type B 0

Offshore 0


Total Miles 0 18.8 348 613.8 902 267.9


1980 - 1989 1990 - 1999 2000 - 2009 2010 - 2019 Total Miles

Transmission

Onshore 40.3 109 90.9 42 2432.7

Offshore 0

Subtotal Transmission 40.3 109 90.9 42 2432.7




Expires: 01/13/2014


Gathering

Onshore Type A 0

Onshore Type B 0

Offshore 0


Total Miles 40.3 109 90.9 42 2432.7






152 171.9 288.2 .7 612.8


75.9 21.3 56.7 2.1 156


185.9 82.7 185.1 1.5 455.2


511.1 242.3 92.8 0 846.2


224.6 76.3 11.1 0 312


0 0 0 0 0




Onshore Totals 1196.2 597.1 635.1 4.3 2432.7

OFFSHORE Class I





All non-steel pipe

Offshore Total

Total Miles 1196.2 2432.7





Offshore 0 0 0 0





Expires: 01/13/2014



Onshore Type B

Offshore

Subtotal Gathering

Total Miles 1196.2 597.1 635.1 4.3 2432.7 306.2



Cause



Segments







0 0 0 0 0


0 0 0 0 0


0 0 0 0 0

Other 0 4 0 0 0

Total 0 14 0 0 0






Onshore Type B


Total 0




Expires: 01/13/2014







TransmissionOnshore 47.5 2381.6 0 3.6 0 0 0 0 0 2432.7


Transmission 47.5 2381.6 0 3.6 0 0 0 0 0 2432.7


Onshore Type B 0 0 0 0 0 0 0 0 0 0


Total Miles 47.5 2381.6 0 3.6 0 0 0 0 0 2432.7



(a)(1) Incomplete

Records

(a)(2) Total

(a)(2) Incomplete

Records

(a)(3) Total

(a)(3) Incomplete

Records

(a)(4) Total

(a)(4) Incomplete

Records

(c)Total

(c)Incomplete

Records

(d)Total

(d) Incomplete

Records

Other1 Total

Other Incomplete

Records

Class 1 (in HCA) 6.23 0 .83 .83 0 0 0 0 .01 0 0 0 0 0


1189.13

0 0 0 0 0 0

Class 2 (in HCA) 11.47 .11 2.48 1.81 0 0 0 0 .09 .07 0 0 0 0


583.06 0 0 0 0 0 0

Class 3 (in HCA) 153.34 11.24 30.54 27.01 0 0 0 0 91.09 7.93 0 0 7.38 0


127.82 17.59 53.5 26.74 0 0 0 0 147.97 17.39 0 0 23.46 0

Class 4 (in HCA) 1.36 .49 0 0 0 0 0 0 1.25 .33 0 .13 .13 0


1.01 .65 0 0 0 0 0 0 .38 .17 0 0 .17 0

Total 2073.42

30.08 87.35 56.39 0 0 0 0 240.79 25.89 0 0 31.14 0

Grand Total 2432.7






operating pressure.


operating pressure.


operating pressure.


operating pressure.




Expires: 01/13/2014




Location


ABLE



ABLE




Class 1 in HCA 6.89 0 0 0 .08 .1

Class 2 in HCA 13.03 .38 0 0 .48 .15

Class 3 in HCA 120.39 12.21 0 .02 24.17 125.57

Class 4 in HCA .96 .12 0 0 .19 1.46

in HCA subTotal 141.27 12.71 0 .02 24.92 127.28

Class 1 not in HCA 790.66 159.25 0 0 70.86 168.36

Class 2 not in HCA 346.18 23.96 0 0 42.29 170.64

Class 3 not in HCA 121.57 11.66 0 0 43.02 176.48

Class 4 not in HCA .61 .08 0 0 .35 .54


Total 1400.29 207.66 0 .02 181.44 643.3


1.25 MAOP > PT ≥ 1.1 MAOP Total .02 Total Miles Internal Inspection NOT ABLE 850.98


Grand Total 2432.71




Expires: 01/13/2014




Alan M. Chichester




Preparer's Title

[email protected]



Mary P. Palkovich

Senior Executive Officer's signature certifying the information in PARTs B, F, G, and M as required by49 U.S.C. 60109(f)


Mary P. Palkovich




[email protected]





Expires: 10/31/2016






GATHERING SYSTEMS


Report Submission

TypeINITIAL

Date Submitted

A federal agency may not conduct or sponsor, and a person is not required to respond to, nor shall a person be subject to a penalty for failure to comply with a collection of information subject to the requirements of the Paperwork Reduction Act unless that collection of information displays a current valid OMB Control Number. The OMB Control Number for this information collection is 2137-0522. Public reporting for this collection of information is estimated to be approximately 22 hours per response, including the time for reviewing instructions, gathering the data needed, and completing and reviewing the collection of information. All responses to this collection of information are mandatory. Send comments regarding this burden estimate or any other aspect of this collection of information, including suggestions for reducing this burden to: Information Collection Clearance Officer, PHMSA, Office of Pipeline Safety (PHP-30) 1200 New Jersey Avenue, SE, Washington, D.C. 20590.

Important: Please read the separate instructions for completing this form before you begin. They clarify the information requested and provide specific examples. If you do not have a copy of the instructions, you can obtain one from the PHMSA Pipeline Safety Community Web Page at http://www.phmsa.dot.gov/pipeline/library/forms.



2748



CMS Energy



JACKSONCity



Natural Gas





8. RESERVED



http://www.phmsa.dot.gov/pipeline/library/forms



Expires: 10/31/2016




Number of HCA Miles

Onshore 309.08

Offshore 0

Total Miles 309.08



Onshore Offshore

Natural Gas 379550

Propane Gas

Synthetic Gas

Hydrogen Gas

Landfill Gas

Other Gas - Name:





Transmission

Onshore 40.12425.29

8 0 2.24 0 0 0 0 0 2467.638

Offshore 0 0 0 0 0 0 0 0 0 0


40.12425.29

8 0 2.24 0 0 0 0 0 2467.638


Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0 0

Subtotal Gathering

0 0 0 0 0 0 0 0 0 0

Total Miles 40.12425.29

8 0 2.24 0 0 0 0 0 2467.638






Expires: 10/31/2016



PARTs F and G








d. Any other internal inspection tools, specify other tools:

1. Internal Inspection Tools - Other













0


0




1. ECDA 7.84

2. ICDA 10.01

3. SCCDA 0


1. ECDA 0




Expires: 10/31/2016


2. ICDA 0

3. SCCDA 0



















d. Total number of actionable anomalies eliminated by pipe replacement in calendar year WITHIN AN HCA SEGMENT: 0

e. Total number of actionable anomalies eliminated by pipe abandonment in calendar year WITHIN AN HCA SEGMENT: 0








Expires: 10/31/2016







Onshore

NPS 4or less 6 8 10 12 14 16 18 20

130.928 45.461 271.541 183.509 509.703 .1 210.214 31.127 187.178

22 24 26 28 30 32 34 36 38

104.822 186.429 383.088 0 16.489 0 0 207.011 0

40 42 44 46 48 52 5658 and

over

0 .04 0 0 0 0 0 0



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and

over




Onshore Type A

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38




Expires: 10/31/2016


40 42 44 46 48 52 5658 and over



Onshore Type B

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 56 58 and over



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and over





Unknown Pre-40 1940 - 1949 1950 - 1959 1960 - 1969 1970 - 1979

Transmission

Onshore 0 12.353 343.865 605.45 907.554 300.23

Offshore 0

Subtotal Transmission 0 12.353 343.865 605.45 907.554 300.23

Gathering

Onshore Type A 0

Onshore Type B 0

Offshore 0


Total Miles 0 12.353 343.865 605.45 907.554 300.23


1980 - 1989 1990 - 1999 2000 - 2009 2010 - 2019 Total Miles

Transmission

Onshore 12.22 111.698 95.777 78.491 2467.638

Offshore 0





Expires: 10/31/2016


Gathering

Onshore Type A 0

Onshore Type B 0

Offshore 0


Total Miles 12.22 111.698 95.777 78.491 2467.638




Steel pipe Less than 20% SMYS 49.819 3.552 .827 0 54.198


161.684 159.993 279.506 .845 602.028


86.792 21.573 56.37 2.057 166.792


206.024 97.701 190.614 1.053 495.392


490.911 262.764 88.183 .617 842.475


231.027 65.684 10.035 0 306.746


0 0 0 0 0




Onshore Totals 1226.257 611.267 625.535 4.572 2467.631

OFFSHORE Class I





All non-steel pipe

Offshore Total

Total Miles 1226.257 2467.631





Offshore 0 0 0 0





Expires: 10/31/2016



Onshore Type B

Offshore

Subtotal Gathering

Total Miles 1226.257 611.267 625.535 4.572 2467.631 309.08



Cause



Segments







0 0 0 0 0


0 0 0 0 0


0 0 0 0 0

Other 0 9 0 0 0

Total 0 16 0 0 0






Onshore Type B


Total 0




Expires: 10/31/2016







Transmission

Onshore 40.1 2425.298 0 2.24 0 0 0 0 0 2467.638


Transmission 40.12425.2

98 0 2.24 0 0 0 0 0 2467.638


Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0Subtotal Gathering

0 0 0 0 0 0 0 0 0 0


980 2.24 0 0 0 0 0 2467.638



(a)(1) Incomplete

Records

(a)(2) Total

(a)(2) Incomplete

Records

(a)(3) Total

(a)(3) Incomplete

Records

(a)(4) Total

(a)(4) Incomplete

Records

(c)Total

(c)Incomplete

Records

(d)Total

(d) Incomplete

Records

Other1 Total

Other Incomplete

Records

Class 1 (in HCA) 6.59 .07 .45 .43 0 0 0 0 0 0 0 0 0 0


1219.62

0 0 0 0 0 0

Class 2 (in HCA) 13.9 .27 1.5 1.3 0 0 0 0 .13 .09 0 0 0 0


595.74 0 0 0 0 0 0

Class 3 (in HCA) 145.37 27.06 33.38 25.16 0 0 0 0 96.01 8.59 0 0 8.18 0


127.95 25.77 53.12 29.63 0 0 0 0 136.39 16.6 0 0 24.73 0

Class 4 (in HCA) 2.18 .12 .03 .02 0 0 0 0 1.28 .35 0 0 .09 0


.48 .01 .01 0 0 0 0 0 .52 .26 0 0 0 0

Total 2111.83

53.3 88.49 56.54 0 0 0 0 234.33 25.89 0 0 33 0

Grand Total 2467.65






operating pressure.


operating pressure.


operating pressure.





Expires: 10/31/2016




Location


ABLE



ABLE




Class 1 in HCA 6.8 .01 0 0 .1 .13

Class 2 in HCA 14.17 .39 0 0 .68 .29

Class 3 in HCA 124.38 12.31 0 .02 17.51 128.73

Class 4 in HCA 1.2 .12 0 0 0 2.25

in HCA subTotal 146.55 12.83 0 .02 18.29 131.4

Class 1 not in HCA 836.26 132.6 0 0 81.2 169.57

Class 2 not in HCA 349.85 17.98 0 0 37.99 189.92

Class 3 not in HCA 121.41 8.21 0 0 37.91 174.66

Class 4 not in HCA .16 .08 0 0 0 .77


Total 1454.23 171.7 0 .02 175.39 666.32




Grand Total 2467.66




Expires: 10/31/2016




Alan M. Chichester




Preparer's Title

[email protected]




Mary P. Palkovich




[email protected]





Expires: 10/31/2017






GATHERING SYSTEMS


Report Submission

TypeINITIAL

Date Submitted





2748



CMS Energy



JACKSONCity



Natural Gas

6. RESERVED




8. RESERVED






Expires: 10/31/2017




Number of HCA Miles

Onshore 315.95

Offshore 0

Total Miles 315.95


☐Check this box and do not complete PART C if this report only includes gathering pipelines or transmission lines of gas distribution systems.

Onshore Offshore

Natural Gas 364942

Propane Gas

Synthetic Gas

Hydrogen Gas

Landfill Gas

Other Gas - Name:





TransmissionOnshore 40.06 2426.85 0 0 0 0 0 0 0 2466.91

Offshore 0 0 0 0 0 0 0 0 0 0


40.06 2426.85 0 0 0 0 0 0 0 2466.91


Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0 0

Subtotal Gathering

0 0 0 0 0 0 0 0 0 0

Total Miles 40.06 2426.85 0 0 0 0 0 0 0 2466.91






Expires: 10/31/2017



PARTs F and G








d. Any other internal inspection tools, specify other tools: 59.6

1. Internal Inspection Tools - Other EMAT











a. Total mileage inspected by pressure testing in calendar year. 53.7


0


1




1. ECDA 37.93

2. ICDA 37.34

3. SCCDA 0


1. ECDA 0




Expires: 10/31/2017


2. ICDA 0

3. SCCDA 0



















d. Total number of actionable anomalies eliminated by pipe replacement in calendar year WITHIN AN HCA SEGMENT:

e. Total number of actionable anomalies eliminated by pipe abandonment in calendar year WITHIN AN HCA SEGMENT:








Expires: 10/31/2017







Onshore

NPS 4or less 6 8 10 12 14 16 18 20

130.47 43.82 275.38 180.59 509.75 .1 210.32 31.13 187.28

22 24 26 28 30 32 34 36 38

104.84 186.44 383.22 0 16.51 0 0 207.02 0

40 42 44 46 48 52 5658 and

over

.04 0 0 0 0 0 0 0



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and

over




Onshore Type A

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38




Expires: 10/31/2017


40 42 44 46 48 52 5658 and over



Onshore Type B

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 56 58 and over



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and over





Unknown Pre-40 1940 - 1949 1950 - 1959 1960 - 1969 1970 - 1979

Transmission

Onshore 0 12.68 331.86 604.15 903.7 299.35

Offshore


Gathering

Onshore Type A

Onshore Type B

Offshore

Subtotal Gathering

Total Miles 0 12.68 331.86 604.15 903.7 299.35


1980 - 1989 1990 - 1999 2000 - 2009 2010 - 2019 Total Miles

Transmission

Onshore 12.22 115.66 97.35 89.94 2466.91

Offshore





Expires: 10/31/2017


Gathering

Onshore Type A

Onshore Type B

Offshore

Subtotal Gathering

Total Miles 12.22 115.66 97.35 89.94 2466.91






109.64 155.67 330.49 1.4 597.2


86.76 18.87 64.75 1.39 171.77


206.84 97.93 191.91 .99 497.67


474.96 244.02 84.72 0 803.7


242.25 78.47 13.26 0 333.98


0 0 0 0 0




Onshore Totals 1176.98 599.83 686.32 3.78 2466.91

OFFSHORE Class I





All non-steel pipe

Offshore Total

Total Miles 1176.98 2466.91





Offshore 0 0 0 0





Expires: 10/31/2017



Onshore Type B

Offshore

Subtotal Gathering

Total Miles 1176.98 599.83 686.32 3.78 2466.91 315.95



Cause



Segments







0 0 0 0 0


0 0 0 0 0


0 0 0 0 0

Other 1 0 0 0 0

Total 2 4 0 0 0






Onshore Type B


Total 0




Expires: 10/31/2017







TransmissionOnshore 40.06 2426.85 0 0 0 0 0 0 0 2466.91



5 0 0 0 0 0 0 0 2466.91


Onshore Type B 0 0 0 0 0 0 0 0 0 0



50 0 0 0 0 0 0 2466.91



(a)(1) Incomplete

Records

(a)(2) Total

(a)(2) Incomplete

Records

(a)(3) Total

(a)(3) Incomplete

Records

(a)(4) Total

(a)(4) Incomplete

Records

(c)Total

(c)Incomplete

Records

(d)Total

(d) Incomplete

Records

Other1 Total

Other Incomplete

Records

Class 1 (in HCA) 6.57 .04 .41 .4 0 0 0 0 .01 0 0 0 0 0


1170 0 0 0 0 0 0

Class 2 (in HCA) 13.89 .27 1.46 1.27 0 0 0 0 .14 .11 0 0 0 0


584.34 0 0 0 0 0 0

Class 3 (in HCA) 160.15 37.67 31.41 23.52 0 0 0 0 90.74 8.23 0 0 8.17 0


149.6 44.18 58.4 31.65 0 0 0 0 163.15 16.94 0 0 24.68 0

Class 4 (in HCA) 1.59 .12 .25 .25 0 0 0 0 1.16 .1 0 0 0 0


.05 .01 .22 .22 0 0 0 0 .52 .2 0 0 0 0

Total 2086.19

82.29 92.15 57.31 0 0 0 0 255.72 25.58 0 0 32.85 0

Grand Total 2466.91






operating pressure.


operating pressure.





Expires: 10/31/2017




Location


ABLE



ABLE




Class 1 in HCA 6.8 0 0 0 .11 .07

Class 2 in HCA 14.24 .35 0 0 .71 .19

Class 3 in HCA 127.8 12.06 0 .02 21.74 128.86

Class 4 in HCA .72 .12 0 0 .76 1.4

in HCA subTotal 149.56 12.53 0 .02 23.32 130.52

Class 1 not in HCA 837.9 127.26 0 0 81.31 123.53

Class 2 not in HCA 358.69 12.14 0 0 38.04 175.47

Class 3 not in HCA 121.57 12.49 0 0 38.64 223.13

Class 4 not in HCA .01 .04 0 0 0 .74


Total 1467.73 164.46 0 .02 181.31 653.39




Grand Total 2466.91




Expires: 10/31/2017




Amanda L. Ward




Preparer's Title

[email protected]




Mary P. Palkovich




[email protected]





Expires: 10/31/2017






GATHERING SYSTEMS


Report Submission

TypeINITIAL

Date Submitted





2748



CMS Energy



JACKSONCity



Natural Gas

6. RESERVED




8. RESERVED






Expires: 10/31/2017




Number of HCA Miles

Onshore 314.76

Offshore 0

Total Miles 314.76


◇Check this box and do not complete PART C if this report only includes gathering pipelines or transmission lines of gas distribution systems.

Onshore Offshore

Natural Gas 331844

Propane Gas

Synthetic Gas

Hydrogen Gas

Landfill Gas

Other Gas - Name:





TransmissionOnshore 40.06 2405.83 0 .89 0 0 0 0 0 2446.78

Offshore 0 0 0 0 0 0 0 0 0 0


40.06 2405.83 0 .89 0 0 0 0 0 2446.78


Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0 0

Subtotal Gathering

0 0 0 0 0 0 0 0 0 0

Total Miles 40.06 2405.83 0 .89 0 0 0 0 0 2446.78






Expires: 10/31/2017



PARTs F and G






















0


0



a. Total mileage inspected by each DA method in calendar year. 108

1. ECDA 47.55

2. ICDA 48.35

3. SCCDA 12.1


1. ECDA 0




Expires: 10/31/2017


2. ICDA 7

3. SCCDA 0








1.Other Inspection Techniques














a. Baseline assessment miles completed during the calendar year. .64






Expires: 10/31/2017







Onshore

NPS 4or less 6 8 10 12 14 16 18 20

124.64 40.883 273.645 179.924 500.577 .1 210.304 31.782 186.906

22 24 26 28 30 32 34 36 38

103.902 187.363 383.175 0 16.542 0 0 207.002 .038

40 42 44 46 48 52 5658 and

over

0 0 0 0 0 0 0 0



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and

over




Onshore Type A

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and over




Expires: 10/31/2017




Onshore Type B

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and over



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

22 24 26 28 30 32 34 36 38

40 42 44 46 48 52 5658 and over





Unknown Pre-40 1940 - 1949 1950 - 1959 1960 - 1969 1970 - 1979

Transmission

Onshore 0 12.56 321.448 599.094 901.276 297.407

Offshore


Gathering

Onshore Type A

Onshore Type B

Offshore

Subtotal Gathering

Total Miles 0 12.56 321.448 599.094 901.276 297.407


1980 - 1989 1990 - 1999 2000 - 2009 2010 - 2019 Total Miles

Transmission

Onshore 9.867 115.463 93.991 95.677 2446.783

Offshore


Gathering




Expires: 10/31/2017


Onshore Type A

Onshore Type B

Offshore

Subtotal Gathering

Total Miles 9.867 115.463 93.991 95.677 2446.783






106.81 155.14 329.17 1.4 592.52


87.46 19.62 65.32 1.39 173.79


199.38 93.05 192.33 .69 485.45


476.31 243.41 84.05 .62 804.39


242.84 74.67 13.51 0 331.02


0 0 0 0 0




Onshore Totals 1168.05 588.94 685.68 4.1 2446.77

OFFSHORE Class I





All non-steel pipe

Offshore Total

Total Miles 1168.05 2446.77





Offshore 0 0 0 0


Gathering




Expires: 10/31/2017


Onshore Type A

Onshore Type B

Offshore

Subtotal Gathering

Total Miles 1168.05 588.94 685.68 4.1 2446.77 314.76



Cause



Segments







0 0 0 0 0


0 0 0 0 0


0 0 0 0 0

Other 0 24 0 0 0

Total 0 30 0 0 0






Onshore Type B


Total 0




Expires: 10/31/2017







TransmissionOnshore 40.06 2405.83 0 .89 0 0 0 0 0 2446.78



3 0 .89 0 0 0 0 0 2446.78


Onshore Type B 0 0 0 0 0 0 0 0 0 0



30 .89 0 0 0 0 0 2446.78



(a)(1) Incomplete

Records

(a)(2) Total

(a)(2) Incomplete

Records

(a)(3) Total

(a)(3) Incomplete

Records

(a)(4) Total

(a)(4) Incomplete

Records

(c)Total

(c)Incomplete

Records

(d)Total

(d) Incomplete

Records

Other1 Total

Other Incomplete

Records

Class 1 (in HCA) 8.03 .04 .14 .13 0 0 0 0 .01 0 0 0 0 0


1159.88

0 0 0 0 0 0

Class 2 (in HCA) 14.54 .3 .74 .54 0 0 0 0 .14 .1 0 0 0 0


573.53 0 0 0 0 0 0

Class 3 (in HCA) 152.54 13.85 31.15 21.35 0 0 0 0 96.28 8.83 0 0 8.17 0


126.8 17.89 63.25 32.18 0 0 0 0 182.81 15.22 0 0 24.69 0

Class 4 (in HCA) 1.59 .12 .25 .25 0 0 0 0 1.18 .1 0 0 0 0


.35 .01 .22 .22 0 0 0 0 .49 .2 0 0 0

Total 2037.26

32.21 95.75 54.67 0 0 0 0 280.91 24.45 0 0 32.86 0

Grand Total 2446.78






operating pressure.


operating pressure.





Expires: 10/31/2017




Location


ABLE



ABLE




Class 1 in HCA 6.8 0 0 0 .11 1.26

Class 2 in HCA 14.51 .02 0 0 .7 .19

Class 3 in HCA 125.78 11.27 0 .02 21.05 130.03

Class 4 in HCA .72 .12 0 0 .76 1.43

in HCA subTotal 147.81 11.41 0 .02 22.62 132.91

Class 1 not in HCA 835.78 124.89 0 0 81.4 117.81

Class 2 not in HCA 356.93 11.37 0 0 39.07 166.16

Class 3 not in HCA 125.18 12.43 0 0 38.62 221.3

Class 4 not in HCA .01 .04 0 0 0 1.01


Total 1465.71 160.14 0 .02 181.71 639.19




Grand Total 2446.77




Expires: 10/31/2017




Amanda L Ward



Gas Regulatory and Compliance Senior Engineer

Preparer's Title

[email protected]




Mary P. Palkovich




[email protected]




18424-AG-CE-100

Question:

73. Refer to Exhibit A-61 (MPP-14), page 12. Please:

a. Explain what the MCA (NPRM) forecasted capital costs on line 23 are for.Identify the components and the basis of the forecast amount.

b. Explain what the Non-HCA Assessments Post NPRM forecasted capital costs online 24 are for. Identify the components and explain the basis of the forecastamount.

Response:

a. The Moderate Consequence Areas (MCA) Notice of Proposed Rulemaking(NPRM) costs are a projection of the ongoing cost to assess approximately one-third of our non-HCA pipeline on a six-year schedule using Direct Assessment.Approximately one-third of our system may meet the MCA definition proposed inthe current Notice of Proposed Rule Making by PHMSA for Pipeline Safety:Safety of Gas Transmission and Gathering Pipelines. The projection utilized theaverage assessment cost per mile for HCA assessments. The cost breakdownwould be approximately the same percentages as shown on Exhibit A-57(MPP-10) page 2, line 3.

b. The Non-HCA Assessments Post (NPRM) costs are a projection of the ongoingcost to assess approximately two-thirds of our Non-HCA (& MCA) pipeline on asix-year schedule using Direct Assessment. Approximately two-thirds of oursystem may not meet the HCA or MCA definition proposed in the current Noticeof Proposed Rule Making by PHMSA for Pipeline Safety: Safety of GasTransmission and Gathering Pipelines. The projection utilized the averageassessment cost per mile for HCA assessments. The cost breakdown would beapproximately the same percentages as shown on Exhibit A-57 (MPP-10) page 2,line 3.



42400089



Request #: 153 Page 1 of 1

.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 01/22/2018 NO. CLC-10 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/30/2018 RESPONDENT: Mary P. Palkovich Question: 1. With reference to Company Exhibit A-61 (MPP-14), please provide the expenditure amounts for

Lines 23 and 24 into what will be incurred by June 30, 2019.

Answer: For purposes of responding to this interrogatory the Company assumes the question is referring to page 13 of Exhibit A-61 (MPP-14). For lines 23 and 24 of page 13 of Exhibit A-61 (MPP-14) the amount projected for January 1 through June 30 of 2019 is $4,506,850.




.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 12/18/2017 NO. CLC-1 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/5/2018 RESPONDENT: Mary P. Palkovich Question: 8. Regarding Part III, Attachment 143 of the rate of the rate case filing requirement, which provided the

2016 pipeline integrity remediation dig information, please provide the same pipeline integrity remediation dig information for 2017. Additionally, provide the capital and/or O&M expense associated with each dig.

Answer:

The information requested will not be available until early February, 2018. The Company will provide this report to the Staff as soon as it is compiled. The Company is still finalizing Pipeline Integrity work in the field.



Page 1 of 31

2017 REMEDIATION DIG SUMMARY U-18424 MPSC Staff Audit Rqst 094

O&M Order # Capital Order # OperationO&M /

Capital Dig HCA County Township Pup Size (ft) Description Anomaly Type

GL-01617 GL-01620 L2800 - Freedom to Clawson

29253045 L2800 - Freedom to Clawson - O&M General

29059668 L2800 - Freedom to Clawson - Capital General

27857680 L2800 - Freedom to Clawson - Dig #2 Capital No Washtenaw Freedom 58

Removed and installed 58' of 18” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #27857680, Kevin Fielder) INTERNAL CLUSTER

30217164 27857690 L2800 - Freedom to Clawson - Dig #4 O&M No Washtenaw Freedom 9.03

Removed and installed 9.03' of 18” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30217164, Kevin Fielder) EXTERNAL CLUSTER

27857811 L2800 - Freedom to Clawson - Dig #9 Capital No Washtenaw Scio 63.8

Removed and installed 63.8' of 18” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #27857811, Kevin Fielder) EXTERNAL ML CORROSION

30217165 27857848 L2800 - Freedom to Clawson - Dig #11 O&M No Washtenaw Scio 9

Removed and installed 9' of 18” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30217165, Kevin Fielder) EXTRA METAL


Removed and installed 42.15' of 18” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP 27857914, Kevin Fielder)

DEFORMATION ANOMALY-DENT


Removed and installed 8.10' of 18” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP 27857914, Kevin Fielder)


30217166 27857919 L2800 - Freedom to Clawson - Dig #17 O&M No Washtenaw Northfield 12.98


27857920 L2800 - Freedom to Clawson - Dig #18 Capital No Washtenaw Northfield 67.79


27857922 L2800 - Freedom to Clawson - Dig #20 Capital No Washtenaw Northfield 0No Pipe Cut-out. >50 Sq Ft Recoated. (SAP #27857922, Kevin Fielder) EXTERNAL ML CORROSION







415.77

GL-01596 GL-01595 L400 - Laingsburg to Fenton

29253048 Line 400 - Laingsburg to Fenton - O&M General

29059670 Line 400 - Laingsburg to Fenton -Capital General

30217160 29901394 Line 400 - Laingsburg to Fenton - Dig #8 O&M No Shiawassee Burns 32.56

Removed and installed 32.56' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #30217160, Mitch Loomis)

EXTRA METAL Possible puddle weld, caliper indicates ID reduction < 1%

29901395 Line 400 - Laingsburg to Fenton - Dig #9 Capital No Shiawassee Burns 55.1

Removed and installed 55.10' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #29901395, Mitch Loomis) EXTRA METAL Possible puddle weld

30217161 29901396 Line 400 - Laingsburg to Fenton - Dig #10 O&M No Shiawassee Antrim 31.66


30217162 29901397 Line 400 - Laingsburg to Fenton - Dig #13 O&M No Shiawassee Antrim 0 Verification Dig, No pipe replaced (SAP #30217162, Mitch Loomis) Attachment



Page 2 of 31




29901398 Line 400 - Laingsburg to Fenton - Dig #14 Capital No Shiawassee Antrim 81.84


30574146 29901399 Line 400 - Laingsburg to Fenton - Dig #15 O&M No Shiawassee Antrim 0 Verification Dig, No pipe replaced (SAP #30574146, Mitch Loomis) EAM WELD ML MANUFACTURING ANOMA

29901580 Line 400 - Laingsburg to Fenton - Dig #20 Capital No Shiawassee Perry 62.33

Removed and installed 62.33' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #29901580, Mitch Loomis) EAM WELD ML MANUFACTURING ANOMA

30217163 29901581 Line 400 - Laingsburg to Fenton - Dig #21 Capital No Shiawassee Perry 51.85


29901582 Line 400 - Laingsburg to Fenton - Dig #23 Capital No Shiawassee Sciota 50.87


29901584 Line 400 - Laingsburg to Fenton - Dig #24 Capital No Shiawassee Sciota 65.62


431.83

GL-01603 GL-01604 L2070 - Dutton to Coolidge

29253049 L2070 - Dutton to Coolidge - O&M General

29253333 L2070 - Dutton to Coolidge - Capital General

28181801 L2070 - Dutton to Coolidge - Dig #3 Capital Yes Oakland Oakland 0No Pipe Removed. New coating installed in excess of 50 sq. ft. (SAP 28181801, Mitch Loomis) DEFORMATION ANOMALY-DENT

28181804 L2070 - Dutton to Coolidge - Dig #6 Capital Yes Oakland Oakland 0No Pipe Removed. New coating installed in excess of 50 sq. ft. (SAP #28181804, Mitch Loomis) EXTRA METAL

0

GL-01741 GL-01766 L2600 - MAR-Processing Plant to Gillow L/R

29014840 L2600 - MAR-Processing Plant to Gillow- O&M General

29059671 L2600 - MAR-Processing Plant to Gillow- Capital Gen.

30977476 L2600 - MAR-Processing Plant to Gillow- Dig #1 Capital No Kalkaska Orange 51.98

Removed and installed 51.98' of 12.75” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline remediation (SAP #30977476, Mitch Loomis) EXTERNAL ML CORROSION


Removed and installed 64.17' of 12.75” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline remediation (SAP #30977477, Mitch Loomis) XTERNAL ML CORROSION assoc. with seam

30977467 30977478 L2600 - MAR-Processing Plant to Gillow- Dig #3 O&M No Kalkaska Orange 21.31

Removed and installed 21.31' of 12.75” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline remediation (SAP #30977467, Mitch Loomis) ML MANUFACTURING ANOMALY


Removed and installed 67.95' of 12.75” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline remediation (SAP #30977479, Mitch Loomis) EXTERNAL ML CORROSION

30977480 L2600 - MAR-Processing Plant to Gillow- Dig #5 Capital No Kalkaska Garfield 50.99

Removed and installed 50.99' of 12.75” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline remediation (SAP #30977480, Mitch Loomis) XTERNAL ML CORROSION assoc. with seam

30977468 30977481 L2600 - MAR-Processing Plant to Gillow- Dig #6 Capital No Kalkaska Garfield 63.36

Removed and installed 63.36' of 12.75” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline remediation (SAP #30977481, Mitch Loomis)

DEFORMATION ANOMALY-DENT Associated with Field Bend

30977469 30977482 L2600 - MAR-Processing Plant to Gillow- Dig #7 Capital No Missaukee Pioneer 0No Pipe Removed. 53.41 sq. ft of new coating installed. (SAP #30977482, Mitch Loomis) Attachment

30977470 30977483 L2600 - MAR-Processing Plant to Gillow- Dig #8 Capital No Missaukee Norwich 65.16

Removed and installed 65.16' of 12.75” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline remediation (SAP #30977483, Mitch Loomis)

DEFORMATION ANOMALY-DENT Associated with Field Bend



Page 3 of 31




30977472 30977484 L2600 - MAR-Processing Plant to Gillow- Dig #9 Capital No Missaukee Norwich 0No Pipe Removed. 56.75 sq. ft of new coating installed. (SAP #30977484, Mitch Loomis) EXTERNAL ML CORROSION

30977473 30977486 L2600 - MAR-Processing Plant to Gillow- Dig #10 O&M No Missaukee Norwich 0No Pipe Removed. 13.35 sq. ft of new coating installed. (SAP #30977473, Mitch Loomis) Extra Metal

30977474 30977488 L2600 - MAR-Processing Plant to Gillow- Dig #11 Capital No Missaukee Enterprise 63.81

Removed and installed 63.81' of 12.75” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline remediation (SAP #30977488, Mitch Loomis) ML MANUFACTURING ANOMALY

448.73

GL-01742 GL-01767 L1200A - KZO-White Pigeon to V Drive South

29014848 L1200A - KZO-White Pigeon to V Drive South - O&M

29059675 L1200A - KZO-White Pigeon to V Drive South - Cap.

30855355 L1200A - KZO-White Pigeon to V Drive - Dig #1 Capital No St Joseph White Pigeon 51.11

Removed and installed 51.11' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855355, Pete Pryson) EXTERNAL ML CORROSION

30855356 L1200A - KZO-White Pigeon to V Drive - Dig #2 Capital No St Joseph Sherman 93.15


30855358 L1200A - KZO-White Pigeon to V Drive - Dig #3 Capital No St Joseph Sherman 0No Pipe Removed. 54.46 sq. ft of new coating installed. (SAP #30855358, Pete Pryson) EXTERNAL ML CORROSION

30855359 L1200A - KZO-White Pigeon to V Drive - Dig #4 Capital No St Joseph Sherman 122.58

Removed and installed 122.58' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855359, Pete Pryson) EXTERNAL SEAM WELD ML CORROSION

30855639 30855501 L1200A - KZO-White Pigeon to V Drive - Dig #5 Capital No St Joseph Sherman 60.28

Removed and installed 60.28' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855501, Pete Pryson) EXTERNAL CLUSTER

30855502 L1200A - KZO-White Pigeon to V Drive - Dig #6 Capital No St Joseph Burr Oak 51.86

Removed and installed 51.86' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855502, Pete Pryson) EAM WELD ANOMALY - A verified with EMA

30855504 L1200A - KZO-White Pigeon to V Drive - Dig #7 Capital No St Joseph Burr Oak 52.14


30855505 L1200A - KZO-White Pigeon to V Drive - Dig #8 Capital No St Joseph Colon 75.36


30855507 L1200A - KZO-White Pigeon to V Drive - Dig #9 Capital No St Joseph Colon 52.38

Removed and installed 52.38' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855507, Pete Pryson) EAM WELD ML MANUFACTURING ANOMA

30855508 L1200A - KZO-White Pigeon to V Drive - Dig #10 Capital No Branch Matteson 52.02


30855511 L1200A - KZO-White Pigeon to V Drive - Dig #11 Capital No Branch Matteson 51

Removed and installed 51' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855511, Pete Pryson) EAM WELD ML MANUFACTURING ANOMA


Removed and installed 50.82' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855512, Pete Pryson) EAM WELD ANOMALY - B verified with EMA


Removed and installed 65.6' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855515, Pete Pryson) ML MANUFACTURING ANOMALY

30855643 30855516 L1200A - KZO-White Pigeon to V Drive - Dig #14 Capital No Branch Batavia 52.97




Page 4 of 31




30855518 L1200A - KZO-White Pigeon to V Drive - Dig #15 Capital No Branch Batavia 50.78


30855519 L1200A - KZO-White Pigeon to V Drive - Dig #16 Capital No Branch Batavia 52

Removed and installed 52' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855519, Pete Pryson) EAM WELD ANOMALY - A verified with EMA



30855523 L1200A - KZO-White Pigeon to V Drive - Dig #18 Capital No Branch Batavia 50.15


30855646 30855526 L1200A - KZO-White Pigeon to V Drive - Dig #19 O&M No Branch Batavia 0No Pipe Removed. No coating installed. (SAP #30855646, Pete Pryson) EXTRA METAL affecting seam weld



30855529 L1200A - KZO-White Pigeon to V Drive - Dig #21 Capital No Branch Union 135.95


30855530 L1200A - KZO-White Pigeon to V Drive - Dig #22 Capital No Branch Union 51.99

Removed and installed 51.99' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855530, Pete Pryson) RMATION ANOMALY-DENT assoc. with girt

30855741 30855532 L1200A - KZO-White Pigeon to V Drive - Dig #23 Cancelled No Branch Girard Cancelled Dig Cancelled Attachment

30855533 L1200A - KZO-White Pigeon to V Drive - Dig #24 Capital No Branch Girard 51.61


30855743 30855535 L1200A - KZO-White Pigeon to V Drive - Dig #25 Capital No Branch Girard 51.89

Removed and installed 51.89' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855535, Pete Pryson) RMATION ANOMALY-DENT assoc. with girt




Removed and installed 81.23' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855539, Pete Pryson) RMATION ANOMALY-DENT assoc. with field

30855744 30855540 L1200A - KZO-White Pigeon to V Drive - Dig #28 Capital No Branch Girard 0No Pipe Removed. 61.27 sq. ft of new coating installed. (SAP #30855540, Pete Pryson) ML MANUFACTURING ANOMALY



30855543 L1200A - KZO-White Pigeon to V Drive - Dig #30 Capital No Branch Butler 53.97


30855545 L1200A - KZO-White Pigeon to V Drive - Dig #31 Capital No Branch Butler 50.85


30855745 30855546 L1200A - KZO-White Pigeon to V Drive - Dig #32 Capital No Calhoun Homer 54.8


30855747 30855548 L1200A - KZO-White Pigeon to V Drive - Dig #33 O&M No Calhoun Homer 0No Pipe Removed. No coating installed. (SAP #30855747, Pete Pryson) EXTRA METAL



Page 5 of 31




30855549 L1200A - KZO-White Pigeon to V Drive - Dig #34 Capital No Calhoun Homer 79.37

Removed and installed 79.37' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #30855549, Pete Pryson) EXTERNAL SEAM WELD CLUSTER

30855741 30855532 L1200A - KZO-White Pigeon to V Drive - Dig #35 O&M No TBD TBD 0No Pipe Removed. 13.62 sq. ft of new coating installed. (SAP #30855741, Pete Pryson)

31243268 L1200A - KZO-White Pigeon to V Drive - EMAT #1 Capital No TBD TBD 52.16

Removed and installed 52.16' of 26"” x 0.500”, SAWL, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline remediation (SAP #31243268, Pete Pryson) Linear anomalies











2168.24

GL-01743 GL-01768 L3200 - FDM-Vector Leslie to Kinder Morgan

29015176 L3200 - FDM-Vector Leslie to Kinder Morgan - O&M

29059676 L3200 - FDM-Vector Leslie to Kinder Morgan - Capital

31322611 31099255 L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #1 O&M No Jackson Rives 0Verification Dig, No pipe Cut-out. Less than than 50 sq.ft of coating installed. (SAP #31322611, Mitch Loomis) ML MANUFACTURING ANOMALY

31099256 L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #2 Capital No Jackson Rives 0

Verification Dig, No pipe Cut-out. Clock-Spring Repair completed over gouges that were buffed out. More than 50 sq.ft of coating installed. (SAP #31099256, Mitch Loomis) EXTERNAL ML CORROSION

31322612 31099257 L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #3 O&M No Jackson Blackman 0Verification Dig, No pipe Cut-out. Less than than 50 sq.ft of coating installed. (SAP #31322612, Mitch Loomis) FORMATION ANOMALY-DENT near girth w

31099258 L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #4 Cancelled Cancelled Cancelled Cancelled Cancelled Cancelled Cancelled

31322613 31099259 L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #5 O&M Yes Jackson Jackson - City 0Verification Dig, No pipe Cut-out. Less than than 50 sq.ft of coating installed. (SAP #31322613, Mitch Loomis) EXTRA METAL

0

GL-01744 GL-01769 L2200 - FDM-Chelsea to Fenton

29015321 L2200 - FDM-Chelsea to Fenton - O&M General

29059677 L2200 - FDM-Chelsea to Fenton - Capital General

30962581 30962387 L2200 - FDM-Chelsea to Fenton - Dig #1 O&M No Washtenaw Sylvan 0

Pipeline remediation assessment, no Pipe Cut-out. Investigated anomaly was on above grade launcher piping. Recoated with Sherwin Williams –Sher-Tar - 2017 Pipeline Remediation – Dig 1 (Superior order #29015321, SAP #30962581, Kevin Fielder)

ML MANUFACTURING ANOMALY near seam weld

30962388 L2200 - FDM-Chelsea to Fenton - Dig #2 Capital No Washtenaw Sylvan 0

Pipeline remediation assessment, no Pipe Cut-out. 8 feet of coating removed and 7 feet of coating removed. Both areas recoated with Trenton Wax - 2017 Pipeline Remediation – Dig 2 (Superior order #29059677, SAP #30962388, Kevin Fielder) INTERNAL ML CORROSION



Page 6 of 31




30962582 30962389 L2200 - FDM-Chelsea to Fenton - Dig #3 Capital No Washtenaw Lima 0

Pipeline remediation assessment, no Pipe Cut-out. 6 feet of coating removed and recoated with Trenton Wax - 2017 Pipeline Remediation – Dig 3 (Superior order #29059677, SAP #30962389, Kevin Fielder) Attachment

30962390 L2200 - FDM-Chelsea to Fenton - Dig #4 Capital No Washtenaw Lima 0

Pipeline remediation assessment, no Pipe Cut-out. 7 feet of coating removed and recoated with Trenton Wax - 2017 Pipeline Remediation – Dig 4 (Superior order #29059677, SAP #30962390, Kevin Fielder)

Manufacturing anomaly / for validation purposes only



Manufacturing anomaly / for validation purposes only



SEAM WELD ML MANUFACTURING ANOMALY

30962583 30962394 L2200 - FDM-Chelsea to Fenton - Dig #7 O&M No Washtenaw Lima 0

Pipeline remediation assessment, no Pipe Cut-out. 2 feet of coating removed and recoated with Trenton Wax - 2017 Pipeline Remediation – Dig 7 (Superior order #29015321, SAP #30962583, Kevin Fielder) EXTRA METAL near seam weld

30962395 L2200 - FDM-Chelsea to Fenton - Dig #8 Capital No Washtenaw Dexter 0

Pipeline remediation assessment, no Pipe Cut-out. 6 feet of coating removed and recoated with Trenton Wax. Close metal object removed near 504+26 - 2017 Pipeline Remediation – Dig 8 (Superior order #29059677, SAP #30962395, Kevin Fielder)






Pipeline remediation assessment, no Pipe Cut-out. 20 feet of coating removed and recoated with Trenton Wax - 2017 Pipeline Remediation – Dig 10 (Superior order #29059677, SAP #30962397, Kevin Fielder) ML MANUFACTURING ANOMALY

30962398 L2200 - FDM-Chelsea to Fenton - Dig #11 Capital No Livingston Oceola 0



30962584 30962399 L2200 - FDM-Chelsea to Fenton - Dig #12 O&M No Livingston Tyrone 23.85

, , , FBE Coated Pipe, pre-construction hydrostatically tested to 1500 +/- 25 psig, Actual minimum test pressure 1478 psig - 2017 Pipeline Remediation – Dig 12 (Superior order #29015321, SAP #30962584, Kevin Fielder)

DEFORMATION ANOMALY-DENT assoc. with field bend

23.85

GL-01745 GL-01770 L2020 - NVL-Pontiac to Decker

29015323 L2020 - NVL-Pontiac to Decker - O&M Gen.

29059678 L2020 - NVL-Pontiac to Decker - Capital Gen.

31167144 30410053 L2020 - NVL-Pontiac to Decker - Dig #1 O&M Yes Oakland Milford 0 Verification Dig, No pipe Cut-out EXTRA METAL

30410054 L2020 - NVL-Pontiac to Decker - Dig #2 Capital No Oakland Commerce 0No Pipe Removed. New coating installed in excess of 50 sq.ft. (SAP #30410054, Walt Bies) ML MANUFACTURING ANOMALY

30410058 30410055 L2020 - NVL-Pontiac to Decker - Dig #3 O&M Yes Oakland Commerce 9.05

Removed and installed 9.05' of 20” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30410058, Walt Bies) MAOP Verification Cut Out

30410056 L2020 - NVL-Pontiac to Decker - Dig #4 Capital Yes Oakland Commerce 57.84

Removed and installed 57.84' of 20” x 0.375”, ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30410056, Walt Bies)


66.89



Page 7 of 31




GL-01746 GL-01771 L3010 - KZO-Olmstead to Galesburg

29015327 Line 3010 -Olmstead to Galesburg - O&M

29059679 Line 3010 -Olmstead to Galesburg - Capital

30855584 Line 3010 -Olmstead to Galesburg - Dig #1 Capital Yes Kalamazoo Kalamazoo 52.1

Removed and installed 52.1' of 12.75” x 0.250”, HFW, API5L-X52, FBE Coated Pipe hydrotested to 1450 +/- 25 psig - 2017 Pipeline Remediation (SAP #30855584, Pete Pryson) INTERNAL ML CORROSION

30855585 Line 3010 -Olmstead to Galesburg - Dig #2 Capital Yes Kalamazoo Kalamazoo 50.5

Removed and installed 50.5' of 12.75” x 0.250”, HFW, API5L-X52, FBE Coated Pipe hydrotested to 1450 +/- 25 psig - 2017 Pipeline Remediation (SAP #30855585, Pete Pryson)


30855587 Line 3010 -Olmstead to Galesburg - Dig #3 Capital No Kalamazoo Comstock 51.1

Removed and installed 51.1' of 12.75” x 0.250”, HFW, API5L-X52, FBE Coated Pipe hydrotested to 1450 +/- 25 psig - 2017 Pipeline Remediation (SAP #30855587, Pete Pryson) ML MANUFACTURING ANOMALY










330.3

GL-01747 GL-01772 L1100 - KZO-Dorr to Middleville Caledonia

29015332 L1100 - KZO-Dorr to Middleville Caledonia - O&M

29059980 L1100 - KZO-Dorr to Middleville Caledonia - Cap.

30705414 L1100 - KZO-Dorr to Middleville Caledonia - Dig #1 Capital No Allegan Dorr 50.91

Removed and installed 50.91' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705414, Pete Pryson) MANUFACTURING ANOMALY near seam w


Removed and installed 50.86' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705415, Pete Pryson) EAM WELD ML MANUFACTURING ANOMA

30705416 L1100 - KZO-Dorr to Middleville Caledonia - Dig #3 Capital No Allegan Dorr 0Verification dig, no pipe cut out. 62.8 Sq.ft of coating replaced. (SAP #30705416, Pete Pryson)

Linear anomaly B / N/A / poss. metal loss anomaly; for validation purposes

only


Removed and installed 50.83' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705417, Pete Pryson) EAM WELD ML MANUFACTURING ANOMA

30705527 30705418 L1100 - KZO-Dorr to Middleville Caledonia - Dig #5 O&M No Allegan Leighton 8.7

Removed and installed 8.7' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705527, Pete Pryson) MAOP Gap

30705528 30705419 L1100 - KZO-Dorr to Middleville Caledonia - Dig #6 O&M No Allegan Leighton 12.77

Removed and installed 12.77' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705528, Pete Pryson) MAOP Gap

30705520 L1100 - KZO-Dorr to Middleville Caledonia - Dig #7 Capital No Allegan Leighton 50.74

Removed and installed 50.74' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705520, Pete Pryson) ML MANUFACTURING ANOMALY


Removed and installed 117.96' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1475 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705521, Pete Pryson) TRA METAL affecting seam weld / Attachm


Removed and installed 143.38' of 24” x 0.375”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705522, Pete Pryson) INTERNAL CLUSTER

30705523 L1100 - KZO-Dorr to Middleville Caledonia - Dig #10 Capital No Allegan Leighton 0Verification dig, no pipe cut out. 53 Sq.ft of coating replaced. (SAP #30705523, Pete Pryson)

Linear anomaly B / N/A / poss. metal loss anomaly; for validation purposes

only



Page 8 of 31




30705529 30705524 L1100 - KZO-Dorr to Middleville Caledonia - Dig #11 Capital No Allegan Leighton 50.72


30705525 L1100 - KZO-Dorr to Middleville Caledonia - Dig #12 Capital No Barry Thornapple 51.31


588.18

GL-01748 GL-01773 L100B - SAG-Herrick to Muskegon

29015337 L100B - SAG-Herrick to Muskegon - O&M Gen.

29059981 L100B - SAG-Herrick to Muskegon - Capital Gen.

30977337 30977324 L100B - SAG-Herrick to Muskegon - Dig #1 Capital No Isabella Vernon 60.1

Removed and installed 60.1' of 36” x 0.532”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30977324, Mitch Loomis) INTERNAL ML CORROSION

30977338 30977326 L100B - SAG-Herrick to Muskegon - Dig #2 Capital No Isabella Vernon 50.34

Removed and installed 50.34' of 36” x 0.532”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30977326, Mitch Loomis) ATION ANOMALY-DENT Associated with F

30977339 30977327 L100B - SAG-Herrick to Muskegon - Dig #3 Capital No Clare Grant 0Verification Dig, No pipe Cut-out. More than 50 sq.ft of coating installed. (SAP #30977327, Mitch Loomis) EXTERNAL ML CORROSION

30977460 30977328 L100B - SAG-Herrick to Muskegon - Dig #4 O&M Yes Clare Surrey 0Verification Dig, No pipe Cut-out. Less than 50 sq.ft of coating installed. (SAP #30977460, Mitch Loomis) MANUFACTURING ANOMALY affecting seam

30977462 29059985 L100B - SAG-Herrick to Muskegon - Dig #5 Capital No Clare Surrey 51.23

Removed and installed 51.23' of 36” x 0.532”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #29059985, Mitch Loomis) ML MANUFACTURING ANOMALY

30977463 30977331 L100B - SAG-Herrick to Muskegon - Dig #6 O&M Yes Clare Lincoln 0Verification Dig, No pipe Cut-out and no coating replacement. (SAP #30977463, Mitch Loomis) Area End Missing Data MFL-A and XT

30977464 30977332 L100B - SAG-Herrick to Muskegon - Dig #7 O&M No Clare Redding 0Verification Dig, No pipe Cut-out and no coating replacement. (SAP #30977464, Mitch Loomis) Attachment

30977465 30977333 L100B - SAG-Herrick to Muskegon - Dig #8 O&M No Clare Redding 0Verification Dig, No pipe Cut-out. Less than 50 sq.ft of coating installed. (SAP #30977465, Mitch Loomis) MANUFACTURING ANOMALY affecting seam

30977466 30977334 L100B - SAG-Herrick to Muskegon - Dig #9 O&M No Clare Winterfield 10

Removed and installed 10' of 36” x 0.532”, ERW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30977466, Mitch Loomis) INTERNAL CLUSTER

171.67

GL-01749 GL-01774 STC-Ira Mainline 20"

29015339 STC-Ira Mainline 20" O&M - General

29059982 STC-Ira Mainline 20" Capital - General

30705401 STC-Ira Mainline 20" Capital - Dig #1 Postponed ostpone Postponed Postponed Postponed Postponed Postponed

30705407 30705402 STC-Ira Mainline 20" Capital - Dig #2 Postponed ostpone Postponed Postponed Postponed Postponed Postponed

30705403 STC-Ira Mainline 20" Capital - Dig #3 Capital No St. Clair Ira 51.96

Removed and installed 51.96ft of 20in x 0.375in, HFW, API5Lx65, FBE coated Pipe hydrotested to 1900 +/- 25 psig - 2017 pipeline remediation (SAP#30705403 ,Walt Bies) INTERNAL ML CORROSION


Removed and installed 50.56 ft of 20in x 0.375in, HFW, API5Lx65, FBE coated Pipe hydrotested to 1900 +/- 25 psig - 2017 pipeline remediation (SAP#30705404 ,Walt Bies) ML MANUFACTURING ANOMALY


Removed and installed 51.45 ft of 20in x 0.375in, HFW, API5Lx65, FBE coated Pipe hydrotested to 1900 +/- 25 psig - 2017 pipeline remediation (SAP#30705405 ,Walt Bies) EAM WELD ML MANUFACTURING ANOMA



Page 9 of 31




153.97

GL-01750 GL-01775 L600 - STC-Clarkston to Squirrel

29059983 L600 - STC-Clarkston to Squirrel - General Capital

31486828 L600 - STC-Clarkston to Squirrel - Dig #1 Capital No Oakland Rose 51.16

Removed and installed 51.16 ft of 22", 0.375" W.T., X-65, ERW, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2017 pipeline remediation (SAP#31486828 ,Walt Bies) ar longitudinal weld anomaly / with corros

31486829 L600 - STC-Clarkston to Squirrel - Dig #2 Capital No Oakland Springfield 53.05

Removed and installed 53.05 ft of 22", 0.375" W.T., X-65, ERW, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2017 pipeline remediation (SAP#31486829 ,Walt Bies) Linear longitudinal weld anomaly

31486830 L600 - STC-Clarkston to Squirrel - Dig #3 Capital Yes Oakland Independence 50.57

Removed and installed 50.57 ft of 22", 0.375" W.T., X-65, ERW, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2017 pipeline remediation (SAP#31486830 ,Walt Bies) ar longitudinal weld anomaly / with corros

31486831 L600 - STC-Clarkston to Squirrel - Dig #4 Postponed Yes Postponed Postponed Postponed Postponed Postponed



31486834 L600 - STC-Clarkston to Squirrel - Dig #7 Postponed No Postponed Postponed Postponed Postponed Postponed

154.78

GL-01751 GL-01776 L1600 - NVL-Northville to Coolidge

29015547 L1600 - NVL-Northville to Coolidge - O&M

29059984 L1600 - NVL-Northville to Coolidge - Capital

30704850 L1600 - NVL-Northville to Coolidge - Dig #1 Capital Yes Wayne Northville 54.84

Removed and installed 54.84 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704850, Kevin Fielder) EAM WELD DENT associated with field ben

30704851 L1600 - NVL-Northville to Coolidge - Dig #2 Capital No Oakland Novi 51.5

Removed and installed 51.5 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704851, Kevin Fielder) SEAM WELD ANOMALY - B

30704852 L1600 - NVL-Northville to Coolidge - Dig #3 Capital Yes Oakland Novi 68.5



Removed and installed 50.47 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704853, Kevin Fielder) EXTERNAL CLUSTER

30704854 L1600 - NVL-Northville to Coolidge - Dig #5 Capital No Oakland Novi 51.69



Removed and installed 50.24 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704855, Kevin Fielder) EXTERNAL SEAM WELD ML CORROSION

31167037 30704856 L1600 - NVL-Northville to Coolidge - Dig #7 O&M Yes Oakland Novi 8.89

Removed and installed 8.89 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #31167037, Kevin Fielder)




Page 10 of 31





Removed and installed 52.49 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704857, Kevin Fielder) EAM WELD ML MANUFACTURING ANOMA

30704858 L1600 - NVL-Northville to Coolidge - Dig #9 Capital Yes Oakland Farmington Hills 60.02



30704859 L1600 - NVL-Northville to Coolidge - Dig #10 Capital No Oakland Farmington Hills 51.53

















Removed and installed 50.46 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704945, Kevin Fielder) ML MANUFACTURING ANOMALY



SEAM WELD DEFORMATION ANOMALY DETECTED W/ METAL LOSS associated

with gouge







30704950 30704949 L1600 - NVL-Northville to Coolidge - Dig #20 O&M Yes Oakland Farmington Hills 0Verification Dig, no pipe cut-out. Under 50 sq. ft of coating replaced. 2017 Remediation (SAP #30704950, Kevin Fielder) ML MANUFACTURING ANOMALY




30704953 L1600 - NVL-Northville to Coolidge - Dig #22 Capital No Oakland Southfield 51

Removed and installed 51 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704953, Kevin Fielder)




Page 11 of 31




30704954 L1600 - NVL-Northville to Coolidge - Dig #23 Capital No Oakland Southfield 57.64



30704956 L1600 - NVL-Northville to Coolidge - Dig #24 Capital Yes Oakland Southfield 51.52






30704958 L1600 - NVL-Northville to Coolidge - Dig #26 Capital No Oakland Southfield 50.48

Removed and installed 50.48 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704958, Kevin Fielder) INTERNAL CLUSTER


Removed and installed 55.78 ft. of 16 in. x 0.375 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1400 +/- 25 psig - 2017 Pipeline Remediation - Dig (Superior order #29059668, SAP #30704980, Kevin Fielder) SEAM WELD DENT






30704983 L1600 - NVL-Northville to Coolidge - Dig #30 Capital Yes Oakland Royal Oak 53.32



31167140 30704984 L1600 - NVL-Northville to Coolidge - Dig #31 O&M Yes Oakland Royal Oak 0Verification Dig, no pipe cut-out. Under 50 sq. ft of coating replaced. 2017 Remediation (SAP #31167140, Kevin Fielder) Attachment

30704985 L1600 - NVL-Northville to Coolidge - Dig #32 Capital Yes Oakland Royal Oak 96.6


SEAM WELD ML MANUFACTURING ANOMALY / SEAM WELD ANOMALY - B

1597.49

GL-01752 GL-01777 L1060 - STC-St. Clair to Mt. Clemens

29015551 L1060 - STC-St. Clair to Mt. Clemens - O&M

29059985 L1060 - STC-St. Clair to Mt. Clemens - Capital

30414402 L1060 - STC-St. Clair to Mt. Clemens - Dig #1 Capital No Macomb Chesterfield 61.59

Removed and installed 61.59 ft. of 12.75 in. x 0.250 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1500 +/- 25 psig - 2017 Pipeline Remediation - Dig (SAP #30414402, Walt Bies) DEFORMATION ANOMALY-DENT


Removed and installed 118.44 ft. of 12.75 in. x 0.250 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1500 +/- 25 psig - 2017 Pipeline Remediation - Dig (SAP #30414404, Walt Bies)

DEFORMATION ANOMALY-DENT possible gouge


Removed and installed 54.8 ft. of 12.75 in. x 0.250 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1500 +/- 25 psig - 2017 Pipeline Remediation - Dig (SAP #30414405, Walt Bies) SEAM WELD DENT



Page 12 of 31




31322617 30414406 L1060 - STC-St. Clair to Mt. Clemens - Dig #4 O&M No Macomb Chesterfield 0.00Verification Dig, No pipe cut-out. 5 sq. ft of coating replaced. (SAP# 31322617, Walt Bies) EXTRA METAL

30414407 L1060 - STC-St. Clair to Mt. Clemens - Dig #5 Capital Yes Macomb Chesterfield 53.55

Removed and installed 53.55 ft. of 12.75 in. x 0.250 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1500 +/- 25 psig - 2017 Pipeline Remediation - Dig (SAP#30414407, Walt Bies) Sleeve






DEFORMATION ANOMALY-DENT possible gouge








Removed and installed 62.02 ft. of 12.75 in. x 0.375 in. W.T., ERW, API5L-X52, ARO Coated Pipe, pre-construction hydrostatically tested to 1900 +/- 25 psig - 2017 Pipeline Remediation - Dig (SAP #30414413, Walt Bies)


30414415 L1060 - STC-St. Clair to Mt. Clemens - Dig #11 Capital No Macomb Macomb 93.38


SEAM WELD DENT ripple - assoc. with field bend

30414416 L1060 - STC-St. Clair to Mt. Clemens - Dig #12 Capital Yes Macomb Clinton 60.92



30414417 L1060 - STC-St. Clair to Mt. Clemens - Dig #13 Capital No Macomb Clinton 61.70

Removed and installed 61.7 ft. of 12.75 in. x 0.250 in. W.T., ERW, API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1500 +/- 25 psig - 2017 Pipeline Remediation - Dig (SAP #30414417, Walt Bies) SEAM WELD DENT



Girth Weld: MAOP Verification Cut-out / Dent


Removed and installed 86.63 ft. of 12.75 in. x 0.375 in. W.T., ARO Coated API5L-X52, FBE Coated Pipe, pre-construction hydrostatically tested to 1500 +/- 25 psig - 2017 Pipeline Remediation - Dig (SAP #30414419, Walt Bies) INTERNAL CLUSTER

31322618 30414460 L1060 - STC-St. Clair to Mt. Clemens - Dig #16 O&M No Macomb Clinton 0.00Verification Dig, No pipe cut-out. No coating replacement. (SAP# 31322618, Walt Bies) Attachment

933.98

GL-01753 GL-01778 L1020 - NVL-South Lyon to Northville

29015555 L1020 - NVL-South Lyon to Northville - O&M

29059986 L1020 - NVL-South Lyon to Northville - Capital

30081398 30081298 L1020 - NVL-South Lyon to Northville - Dig #1 Capital No Oakland Lyon 0No Pipe Removed. New coating installed in excess of 50 sq. ft. (SAP #30081298, Kevin Fielder)

DEFORMATION ANOMALY-DENT assoc. with field bend

30081299 L1020 - NVL-South Lyon to Northville - Dig #2 Capital No Oakland Lyon 51.52

Removed and installed 51.52' of 16” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30081299, Kevin Fielder)




Page 13 of 31




30081321 L1020 - NVL-South Lyon to Northville - Dig #3 Capital No Oakland Lyon 55.29

Removed and installed 55.29' of 16” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30081321, Kevin Fielder) INTERNAL CLUSTER

30081322 L1020 - NVL-South Lyon to Northville - Dig #4 Capital Yes Washtenaw Salem 50.25

Removed and installed 50.25' of 16” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30081322, Kevin Fielder)


30081427 30081324 L1020 - NVL-South Lyon to Northville - Dig #5 O&M No Washtenaw Salem 13.06

Removed and installed 13.06' of 16” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30081427, Kevin Fielder) SEAM WELD DENT

30081446 30081325 L1020 - NVL-South Lyon to Northville - Dig #6 Capital No Washtenaw Salem 100.34

Removed and installed 100.34' of 16” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30081325, Kevin Fielder) EXTERNAL ML CORROSION

30081449 30081327 L1020 - NVL-South Lyon to Northville - Dig #7 O&M No Washtenaw Salem 10

Removed and installed 10' of 16” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP # 30081449, Kevin Fielder) ML MANUFACTURING ANOMALY

280.46

GL-01754 GL-01779 L250 - SAG-Mt Pleasant to Zilwaukee

30217102 L250 - SAG-Mt Pleasant to Zilwaukee - O&M Gen.

29059987 L250 - SAG-Mt Pleasant to Zilwaukee - Capital Gen.

30216956 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1 Capital Yes Isabella Union 51.15

Removed and installed 51.15' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30216956, Mitch Loomis) SEAM WELD ANOMALY - B

30216957 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #2 Capital Yes Isabella Chippewa 70.89

Removed and installed 70.89' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30216957, Mitch Loomis) ML MANUFACTURING ANOMALY

30217103 30216958 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #3 Capital No Isabella Chippewa 56.6

Removed and installed 56.6' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30216958, Mitch Loomis)


30216959 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #4 Capital No Isabella Chippewa 180.01




Removed and installed 59.09' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30217080, Mitch Loomis) SEAM WELD ANOMALY - A

30217104 30217081 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #6 Capital No Isabella Chippewa 64.5


DEFORMATION ANOMALY-DENT with weld







30217084 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #9 Capital No Midland Greendale 51.34

Removed and installed 51.34' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30217084, Mitch Loomis) SEAM WELD ANOMALY - B

30217105 30217085 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #10 Capital No Midland Greendale 57.11

Removed and installed 57.11' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30217085, Mitch Loomis) DEFORMATION ANOMALY-DENT

30217106 30217086 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #11 Capital No Midland Greendale 56.89


DEFORMATION ANOMALY-DENT with weld



Page 14 of 31




30217107 30217087 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #12 Capital No Midland Ingersoll 53.5


DEFORMATION ANOMALY possible gouge - 0.7% - Min ID = 15.39 in.

30217088 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #13 Capital No Midland Ingersoll 56.35



30217108 30217089 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #14 Capital No Midland Ingersoll 0No Pipe Removed. 124 sq. ft of new coating installed. (SAP #30217089, Mitch Loomis) EXTRA METAL near seam weld

30217109 30217090 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #15 Capital No Midland Ingersoll 57.7



30217110 30217091 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #16 Cancelled No Midland Ingersoll Cancelled Dig was assessed before so the dig was cancelled. Area Start Attachment 09:00 to 03:00

30217092 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #17 Capital No Midland Ingersoll 58.18

Removed and installed 58.18' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP 30217092, Mitch Loomis)


30217111 30217093 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #18 Capital No Saginaw Tittabawassee 0No Pipe Removed. 54.73 sq. ft of new coating installed. (SAP #30217093, Mitch Loomis) Attachment

30217112 30217094 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #19 Capital No Saginaw Tittabawassee 57.18

Removed and installed 57.18' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30217094, Mitch Loomis) ML MANUFACTURING ANOMALY

30217113 30217095 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #20 Capital No Saginaw Tittabawassee 57.84


DEFORMATION ANOMALY possible gouge - 0.8% - Min ID = 15.25 in.

30217115 30217097 L250 - SAG-Mt Pleasant to Zilwaukee - MAOP Dig #22 O&M Yes Isabella Union 12.09

Removed and installed 12.09' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #30217115, Mitch Loomis) MAOP GAP

30217116 30217098 L250 - SAG-Mt Pleasant to Zilwaukee - MAOP Dig #23 Capital Yes Isabella Union 56.21


30217117 30217099 L250 - SAG-Mt Pleasant to Zilwaukee - MAOP Dig #24 Capital No Isabella Chippewa 67.12


1383.69

GL-01755 GL-01780 L1800 - KZO-Schoolcraft to Plainwell

29015754 L1800 - KZO-Schoolcraft to Plainwell - O&M

29059988 L1800 - KZO-Schoolcraft to Plainwell - Capital

30414463 L1800 - KZO-Schoolcraft to Plainwell - Dig #1 Capital No Kalamazoo Prairie Ronde 65.28

Removed and installed 65.28' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30414463, Pete Pryson) EAM WELD ML MANUFACTURING ANOMAL

30414464 L1800 - KZO-Schoolcraft to Plainwell - Dig #2 Capital No Kalamazoo Texas 81.48

Removed and installed 81.48' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30414464, Pete Pryson) EAM WELD ML MANUFACTURING ANOMA

30414465 L1800 - KZO-Schoolcraft to Plainwell - Dig #3 Capital Yes Kalamazoo Texas 58.07


30414466 L1800 - KZO-Schoolcraft to Plainwell - Dig #4 Capital No Kalamazoo Oshtemo 79.93

Removed and installed 79.93' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30414466, Pete Pryson) UFACTURING ANOMALY Repaired by grindi

30414467 L1800 - KZO-Schoolcraft to Plainwell - Dig #5 Cancelled Yes Kalamazoo Oshtemo Cancelled Dig was cancelled ML MANUFACTURING ANOMALY

30414468 L1800 - KZO-Schoolcraft to Plainwell - Dig #6 Capital Yes Kalamazoo Oshtemo 69.38

Removed and installed 69.38' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30414468, Pete Pryson) Sleeve



Page 15 of 31




30414469 L1800 - KZO-Schoolcraft to Plainwell - Dig #7 Capital Yes Kalamazoo Oshtemo 0No Pipe Cut out. 57.57 sq. ft of new coating installed (SAP #30414469, Pete Pryson ML MANUFACTURING ANOMALY

30414470 L1800 - KZO-Schoolcraft to Plainwell - Dig #8 Capital No Kalamazoo Oshtemo 78.26

Removed and installed 78.26' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30414470, Pete Pryson) ML MANUFACTURING ANOMALY

30977490 30414471 L1800 - KZO-Schoolcraft to Plainwell - Dig #9 O&M No Kalamazoo Alamo 30.5


30414477 30414472 L1800 - KZO-Schoolcraft to Plainwell - Dig #10 O&M Yes Allegan Otsego 0Verification dig. Less than 2 sq. ft of re-coating. (SAP# 30414477, Pete Pryson) Extra Metal

30414478 30414473 L1800 - KZO-Schoolcraft to Plainwell - Dig #11 O&M Yes Allegan Otsego 0Verification dig. Less than 2 sq. ft of re-coating. (SAP# 30414478, Pete Pryson) Attachment

30414474 L1800 - KZO-Schoolcraft to Plainwell - Dig #12 Capital Yes Allegan Otsego 68.55

Removed and installed 68.55' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30414474, Pete Pryson) Sleeve

531.45

GL-01756 GL-01781 L1800 - KZO-White Pigeon to Schoolcraft

29016067 L1800 - KZO-White Pigeon to Schoolcraft - O&M

29059989 L1800 - KZO-White Pigeon to Schoolcraft - Capital

30146577 L1800 - KZO-White Pigeon to Schoolcraft - Dig #1 Capital No St. Joseph White Pigeon 57.44

Removed and installed 57.44' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30146577, Pete Pryson) EXTERNAL CLUSTER

30146643 L1800 - KZO-White Pigeon to Schoolcraft - Dig #2 Capital No St. Joseph White Pigeon 85.05

Removed and installed 85.05' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30146643, Pete Pryson) EXTERNAL SEAM WELD ML CORROSION

30146649 L1800 - KZO-White Pigeon to Schoolcraft - Dig #3 Capital No St. Joseph Florence 80.3

Removed and installed 80.30' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30146649, Pete Pryson)





30146767 30146702 L1800 - KZO-White Pigeon to Schoolcraft - Dig #5 Capital No St. Joseph Florence 0Verification dig. 52.33 ft of new coating installed. (SAP #30146702, Pete Pryson) EXTERNAL CLUSTER




30146716 L1800 - KZO-White Pigeon to Schoolcraft - Dig #7 Capital No St. JosephFlorence &

Constantine 1946.25

Removed and installed 1946.25' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30146716, Pete Pryson) SEAM WELD ANOMALY - B

30146724 L1800 - KZO-White Pigeon to Schoolcraft - Dig #8 Capital No St. Joseph Fabius 95.92



30146768 30146731 L1800 - KZO-White Pigeon to Schoolcraft - Dig #9 Capital No St. Joseph Fabius 0Verification dig. 88.96 ft of new coating installed. (SAP #30146731, Pete Pryson) EXTRA METAL

30146734 L1800 - KZO-White Pigeon to Schoolcraft - Dig #10 Capital No St. Joseph Fabius 69.62



30146769 30146735 L1800 - KZO-White Pigeon to Schoolcraft - Dig #11 O&M No St. Joseph Flowerfield 17.96

Removed and installed 17.96' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30146769, Pete Pryson) SEAM WELD DENT

30146737 L1800 - KZO-White Pigeon to Schoolcraft - Dig #12 Capital No St. Joseph Flowerfield 72.33


30146770 30146738 L1800 - KZO-White Pigeon to Schoolcraft - Dig #13 Capital No St. Joseph Flowerfield 75.44

Removed and installed 75.44' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30146738, Pete Pryson) ML MANUFACTURING ANOMALY





Page 16 of 31









30146762 L1800 - KZO-White Pigeon to Schoolcraft - Dig #17 Capital No Kalamazoo Prairie Ronde 77

Removed and installed 77' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30146762, Pete Pryson)


30146763 L1800 - KZO-White Pigeon to Schoolcraft - Dig #18 Capital No Kalamazoo Prairie Ronde 73.13

Removed and installed 73.13' of 20” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30146763, Pete Pryson) SEAM WELD ANOMALY - A

30146764 L1800 - KZO-White Pigeon to Schoolcraft - Dig #19 Postponed No Kalamazoo Prairie Ronde Postponed Postponed to 2018 SEAM WELD ANOMALY - B

3037.3

GL-01757 GL-01782 L1800 - KZO-Plainwell to 30th

29016623 L1800 - KZO-Plainwell to 30th - O&M

29059990 L1800 - KZO-Plainwell to 30th - Capital

30120723 30120605 L1800 - KZO-Plainwell to 30th - Dig #1 Capital No Allegan Watson 82.11

Removed and installed 82.11' of 20” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30120605, Pete Pryson) Attachment

30120607 L1800 - KZO-Plainwell to 30th - Dig #2 Capital No Allegan Watson 81.72

Removed and installed 81.72' of 20” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30120607, Pete Pryson)


30120724 30120608 L1800 - KZO-Plainwell to 30th - Dig #3 Capital No Allegan Watson 52.85

Removed and installed 52.85' of 20” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30120608, Pete Pryson) ML MANUFACTURING ANOMALY

30120609 L1800 - KZO-Plainwell to 30th - Dig #4 Capital No Allegan Watson 75.96

Removed and installed 75.96' of 20” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30120609, Pete Pryson) SEAM WELD ANOMALY - B

30120610 L1800 - KZO-Plainwell to 30th - Dig #5 Capital No Allegan Hopkins 225.5







30120613 L1800 - KZO-Plainwell to 30th - Dig #8 Capital No Allegan Monterey 020" x 0.500" API5L-X65 Petrosleeve with Trenton Wax coating over 50 Sq. ft. (SAP #30120613, Pete Pryson) SEAM WELD ANOMALY - A

30120614 L1800 - KZO-Plainwell to 30th - Dig #9 Capital No Allegan Monterey 68.88








30120617 L1800 - KZO-Plainwell to 30th - Dig #12 Capital No Allegan Monterey 0Verification Dig, No pipe Cut-out. 68 Sq.ft of coating replaced. (SAP #30120617, Pete Pryson) ML MANUFACTURING ANOMALY

30120725 30120619 L1800 - KZO-Plainwell to 30th - Dig #13 O&M No Allegan Salem 0Verification Dig, No pipe Cut-out. 0 Sq.ft of coating replaced. (SAP #30120725, Pete Pryson) EXTRA METAL near seam weld



Page 17 of 31




30120726 30120720 L1800 - KZO-Plainwell to 30th - Dig #14 O&M No Allegan Salem 29.62

Removed and installed 29.62' of 20” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation. Dig also included a 0.500" SMLS, WPHY 52 3DR 90 Segmentable elbow. (SAP #30120726, Pete Pryson) Bend Miter Bend 7.4D - 10° - Right

30120727 30120721 L1800 - KZO-Plainwell to 30th - Dig #15 O&M No Allegan Salem 43.2

Removed and installed 43.2' of 20” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30120727, Pete Pryson) Bend Miter Bend 3.3D - 21° - Right

934.97

GL-01759 GL-01784 L100C - SAG-Airport to Herrick

29016634 L100C - SAG-Airport to Herrick - O&M General

29059992 L100C - SAG-Airport to Herrick - Capital General

31166470 L100C - SAG-Airport to Herrick - Dig #1 Capital No Isabella Union 105.29

Removed and installed 105.29' of 16” x .0312"/0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166470, Mitch Loomis) INTERNAL CLUSTER


Removed and installed 64.97' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166471, Mitch Loomis) N ANOMALY-DENT associated with possibl


Removed and installed 142.07' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166472, Mitch Loomis) MANUFACTURING ANOMALY under attachm


Removed and installed 137.87' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166473, Mitch Loomis) MANUFACTURING ANOMALY under attachm


Removed and installed 52.46' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166474, Mitch Loomis) EXTERNAL CLUSTER

31166475 L100C - SAG-Airport to Herrick - Dig #6 Capital No Isabella Isabella 125.06

Removed and installed 125.06' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166475, Mitch Loomis) EXTERNAL SEAM WELD ML CORROSION


Removed and installed 66.59 ' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166476, Mitch Loomis) EXTERNAL CLUSTER








Removed and installed 168.37' of 16” x 0.312"/0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166520, Mitch Loomis) DENT DETECTED W/ METAL LOSS ripple




Removed and installed 210.88' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166522, Mitch Loomis) EXTERNAL SEAM WELD CLUSTER


Removed and installed 268.07' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166523, Mitch Loomis) EXTERNAL CLUSTER near seam weld





Page 18 of 31







Removed and installed 104.22' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP#31166526, Mitch Loomis) EXTERNAL SEAM WELD CLUSTER








Removed and installed 120.30' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hyd.30rotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166530, Mitch Loomis) EXTERNAL SEAM WELD ML CORROSION









31166535 L100C - SAG-Airport to Herrick - Dig #26 Capital No Isabella Isabella201.45

Removed and installed 201.45' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 EAM WELD ML MANUFACTURING ANOMA

31166567 31166537 L100C - SAG-Airport to Herrick - Dig #27 Capital No Isabella Isabella DEFORMATION ANOMALY-DENT associated with g

31166538 L100C - SAG-Airport to Herrick - Dig #28 Capital No Isabella Vernon 104.53

Removed and installed 104.53' of 16” x 0.312"/ 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166538, Mitch Loomis) EXTERNAL SEAM WELD ML CORROSION




Removed and installed 62.08' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166560, Mitch Loomis) EAM WELD ML MANUFACTURING ANOMA


Removed and installed 55.97' of 16” x 0.312" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166561, Mitch Loomis) EAM WELD ML MANUFACTURING ANOMA

31166568 31166562 L100C - SAG-Airport to Herrick - Dig #32 Capital No Isabella Vernon 52.79

Removed and installed 52.79' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166562, Mitch Loomis) FORMATION ANOMALY-DENT possible gou


Removed and installed 50.88' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31166564, Mitch Loomis) DEFORMATION ANOMALY-DENT

31322604 L100C - SAG-Airport to Herrick - EMAT #1 Capital No Isabella Isabella 54.29

Removed and installed 54.29' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31322604, Mitch Loomis) Linear longitudinal weld anomaly


Removed and installed 56.61' of 16” x 0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31322605, Mitch Loomis) Linear anomaly B / for validation purposes



Page 19 of 31






31322607 L100C - SAG-Airport to Herrick - EMAT #4 Capital No Isabella Vernon 55.46





Removed and installed 96.10' of 16” x 0.312"/0.375" W.T., HFW, API5L-X52, FBE Coated Pipe hydrotested to 1400 +/- 25 psig - 2017 Pipeline Remediation (SAP #31322610, Mitch Loomis) Linear longitudinal weld anomaly

4242.62

GL-01760 GL-01785 L1080 - FDM-Maple Dale to Park Rd

29016636 L1080 - FDM-Maple Dale to Park Rd - O&M

29059993 L1080 - FDM-Maple Dale to Park Rd - Capital

30466435 L1080 - FDM-Maple Dale to Park Rd - Dig #1 O&M No Jackson Liberty 0 Verification Dig - No Pipe Cut-out GIRTHWELD ANOMALY

30466436 30705533 L1080 - FDM-Maple Dale to Park Rd - Dig #2 Capital No Jackson Liberty 0Verification Dig - No Pipe Cut-out. > 50 sq. ft of coating replaced (SAP #30705533, Kevin Fielder) ML MANUFACTURING ANOMALY

30466437 L1080 - FDM-Maple Dale to Park Rd - Dig #3 O&M No Jackson Liberty 0 Verification Dig - No Pipe Cut-out (SAP #30466437, Kevin Fielder) Attachment possible patch

30466438 L1080 - FDM-Maple Dale to Park Rd - Dig #4 O&M No Jackson Summit 0 Verification Dig - No Pipe Cut-out (SAP #30466438, Kevin Fielder) EXTRA METAL

30466439 L1080 - FDM-Maple Dale to Park Rd - Dig #5 O&M Yes Jackson Summit 0 Verification Dig - No Pipe Cut-out (SAP #30466439, Kevin Fielder) ML MANUFACTURING ANOMALY

30466585 L1080 - FDM-Maple Dale to Park Rd - Dig #6 Capital Yes Jackson Summit 120.3

Removed and installed 120.3' of 12.75” x 0.250" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30466585, Kevin Fielder) ML MANUFACTURING ANOMALY

30466580 30705534 L1080 - FDM-Maple Dale to Park Rd - Dig #7 Capital Yes Jackson Summit 52.23

Removed and installed 52.23' of 12.75” x 0.250" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30705534, Kevin Fielder) DENT

30466587 L1080 - FDM-Maple Dale to Park Rd - Dig #8 Capital Yes Jackson Summit 54.99

Removed and installed 54.99' of 12.75” x 0.250" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30466587, Kevin Fielder) GIRTHWELD ANOMALY / MAOP Gap

30466582 L1080 - FDM-Maple Dale to Park Rd - Dig #9 O&M Yes Jackson Summit 19.93

Removed and installed 19.93' of 12.75” x 0.250" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2017 Pipeline Remediation (SAP #30466582, Kevin Fielder) Girth Weld / MAOP Gap

247.45

GL-01762 GL-01787 L2500 - M72 VS to Shell Processing Plant

29016761 L2500 - M72 VS to Shell Processing Plant - O&M

29059995 L2500 - M72 VS to Shell Processing Plant - Capital

30574083 L2500 - M72 VS to Shell Processing Plant - Dig #1 Capital No Kalkaska Bear Lake 73.46

Removed and installed 73.46' of 12.75” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline Remediation (SAP #30574083, Mitch Loomis) ML MANUFACTURING ANOMALY

30574098 30574084 L2500 - M72 VS to Shell Processing Plant - Dig #2 O&M No Kalkaska Bear Lake 34.44

Removed and installed 34.44' of 12.75” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline Remediation (SAP #30574098, Mitch Loomis)


30574085 L2500 - M72 VS to Shell Processing Plant - Dig #3 Capital No Kalkaska Bear Lake 62

Removed and installed 62' of 12.75” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline Remediation (SAP #30574085, Mitch Loomis)


30574099 30574086 L2500 - M72 VS to Shell Processing Plant - Dig #4 O&M Yes Kalkaska Bear Lake 0No Pipe Cut out, Less than 50 sq. ft of coating (SAP #30574099, Mitch Loomis)




Page 20 of 31




30574140 30574087 L2500 - M72 VS to Shell Processing Plant - Dig #5 O&M No Kalkaska Excelsior 0No Pipe Cut out, Less than 50 sq. ft of coating (SAP #30574140, Mitch Loomis)

EXTRA METAL near seam weld

30574088 L2500 - M72 VS to Shell Processing Plant - Dig #6 Capital No Kalkaska Excelsior 58.64



30574141 30574089 L2500 - M72 VS to Shell Processing Plant - Dig #7 O&M No Kalkaska Excelsior 9.84


EXTRA METAL near seam weld, possible puddle weld

30574090 L2500 - M72 VS to Shell Processing Plant - Dig #8 Capital No Kalkaska Kalkaska 62.33






30574142 30574093 L2500 - M72 VS to Shell Processing Plant - Dig #10 O&M No Kalkaska Kalkaska 41.95


ML MANUFACTURING ANOMALY

30574143 30574094 L2500 - M72 VS to Shell Processing Plant - Dig #11 O&M No Kalkaska Kalkaska 9.17


SEAM WELD DENT




30574144 30574096 L2500 - M72 VS to Shell Processing Plant - Dig #13 O&M Yes Kalkaska Kalkaska 39

Removed and installed 39' of 12.75” x 0.375" W.T., ERW, API5L-X52, FBE Coated Pipe hydrotested to 1900 +/- 25 psig - 2017 Pipeline Remediation (SAP #30574144, Mitch Loomis)


518.84



Page 21 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 094GL-01617 GL-01620 L2800 - Freedom to Clawson29253045 45,247 L2800 - Freedom to Clawson - O&M General

29059668 656,340 L2800 - Freedom to Clawson - Capital General27857680 222,236 L2800 - Freedom to Clawson - Dig #2

30217164 177,638 27857690 - L2800 - Freedom to Clawson - Dig #427857811 397,990 L2800 - Freedom to Clawson - Dig #9

30217165 148,929 27857848 - L2800 - Freedom to Clawson - Dig #1127857914 292,705 L2800 - Freedom to Clawson - Dig #16

30217166 221,006 27857919 - L2800 - Freedom to Clawson - Dig #1727857920 84,508 L2800 - Freedom to Clawson - Dig #1827857922 215,871 L2800 - Freedom to Clawson - Dig #2027857925 151,296 L2800 - Freedom to Clawson - Dig #2327857926 154,277 L2800 - Freedom to Clawson - Dig #24

GL-01596 GL-01595 L400 - Laingsburg to Fenton29253048 527,482 Line 400 - Laingsburg to Fenton - O&M General

29059670 328,892 Line 400 - Laingsburg to Fenton -Capital General30217160 387,088 29901394 - Line 400 - Laingsburg to Fenton - Dig #8

29901395 510,836 Line 400 - Laingsburg to Fenton - Dig #930217161 382,472 29901396 - Line 400 - Laingsburg to Fenton - Dig #1030217162 52,102 29901397 - Line 400 - Laingsburg to Fenton - Dig #13

29901398 239,653 Line 400 - Laingsburg to Fenton - Dig #1430574146 95,836 29901399 - Line 400 - Laingsburg to Fenton - Dig #15

29901580 412,016 Line 400 - Laingsburg to Fenton - Dig #2030217163 29901581 291,286 Line 400 - Laingsburg to Fenton - Dig #21

29901582 514,957 Line 400 - Laingsburg to Fenton - Dig #2329901584 310,534 Line 400 - Laingsburg to Fenton - Dig #24

GL-01603 GL-01604 L2070 - Dutton to Coolidge29253049 - L2070 - Dutton to Coolidge - O&M General

29253333 177,393 L2070 - Dutton to Coolidge - Capital General28181801 193,886 L2070 - Dutton to Coolidge - Dig #328181804 506,320 L2070 - Dutton to Coolidge - Dig #6

GL-01741 GL-01766 L2600 - MAR-Processing Plant to Gillow L/R29059671 280,144 L2600 - MAR-Processing Plant to Gillow- Capital Gen.30977476 73,235 L2600 - MAR-Processing Plant to Gillow- Dig #1

30977473 30977486 41,411 L2600 - MAR-Processing Plant to Gillow- Dig #1030977474 30977488 71,360 L2600 - MAR-Processing Plant to Gillow- Dig #11



Page 22 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09430977477 84,157 L2600 - MAR-Processing Plant to Gillow- Dig #2

30977467 30977478 55,545 L2600 - MAR-Processing Plant to Gillow- Dig #330977479 58,037 L2600 - MAR-Processing Plant to Gillow- Dig #430977480 85,626 L2600 - MAR-Processing Plant to Gillow- Dig #5

30977468 30977481 79,868 L2600 - MAR-Processing Plant to Gillow- Dig #630977469 30977482 36,183 L2600 - MAR-Processing Plant to Gillow- Dig #730977470 30977483 73,949 L2600 - MAR-Processing Plant to Gillow- Dig #830977472 30977484 39,330 L2600 - MAR-Processing Plant to Gillow- Dig #929014840 194 L2600 - MAR-Processing Plant to Gillow- O&M General

GL-01742 GL-01767 L1200A - KZO-White Pigeon to V Drive South29014848 2,221 L1200A - KZO-White Pigeon to V Drive South - O&M

29059675 1,312,679 L1200A - KZO-White Pigeon to V Drive South - Cap.30855355 145,225 L1200A - KZO-White Pigeon to V Drive - Dig #130855356 152,663 L1200A - KZO-White Pigeon to V Drive - Dig #230855358 57,490 L1200A - KZO-White Pigeon to V Drive - Dig #330855359 203,694 L1200A - KZO-White Pigeon to V Drive - Dig #4

30855639 30855501 215,859 L1200A - KZO-White Pigeon to V Drive - Dig #530855502 102,038 L1200A - KZO-White Pigeon to V Drive - Dig #630855504 198,390 L1200A - KZO-White Pigeon to V Drive - Dig #730855505 135,422 L1200A - KZO-White Pigeon to V Drive - Dig #830855507 106,800 L1200A - KZO-White Pigeon to V Drive - Dig #930855508 119,868 L1200A - KZO-White Pigeon to V Drive - Dig #1030855511 114,393 L1200A - KZO-White Pigeon to V Drive - Dig #1130855512 178,748 L1200A - KZO-White Pigeon to V Drive - Dig #1230855515 159,996 L1200A - KZO-White Pigeon to V Drive - Dig #13

30855643 30855516 112,482 L1200A - KZO-White Pigeon to V Drive - Dig #1430855518 103,534 L1200A - KZO-White Pigeon to V Drive - Dig #1530855519 88,758 L1200A - KZO-White Pigeon to V Drive - Dig #16

30855645 30855522 112,908 L1200A - KZO-White Pigeon to V Drive - Dig #1730855523 147,197 L1200A - KZO-White Pigeon to V Drive - Dig #18

30855646 30855526 34,075 L1200A - KZO-White Pigeon to V Drive - Dig #1930855657 30855527 103,303 L1200A - KZO-White Pigeon to V Drive - Dig #20

30855529 179,312 L1200A - KZO-White Pigeon to V Drive - Dig #2130855530 210,818 L1200A - KZO-White Pigeon to V Drive - Dig #22

30855741 30855532 46,091 L1200A - KZO-White Pigeon to V Drive - Dig #2330855533 86,942 L1200A - KZO-White Pigeon to V Drive - Dig #24

30855743 30855535 117,874 L1200A - KZO-White Pigeon to V Drive - Dig #2530855536 121,314 L1200A - KZO-White Pigeon to V Drive - Dig #2630855539 205,224 L1200A - KZO-White Pigeon to V Drive - Dig #27



Page 23 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09430855744 30855540 59,327 L1200A - KZO-White Pigeon to V Drive - Dig #28

30855542 169,025 L1200A - KZO-White Pigeon to V Drive - Dig #2930855543 115,435 L1200A - KZO-White Pigeon to V Drive - Dig #3030855545 91,992 L1200A - KZO-White Pigeon to V Drive - Dig #31

30855745 30855546 248,205 L1200A - KZO-White Pigeon to V Drive - Dig #3230855747 30855548 44,994 L1200A - KZO-White Pigeon to V Drive - Dig #33

30855549 192,969 L1200A - KZO-White Pigeon to V Drive - Dig #3431243268 81,785 L1200A - KZO-White Pigeon to V Drive - EMAT #131243269 90,870 L1200A - KZO-White Pigeon to V Drive - EMAT #231243270 83,526 L1200A - KZO-White Pigeon to V Drive - EMAT #331243271 84,245 L1200A - KZO-White Pigeon to V Drive - EMAT #431243272 154,342 L1200A - KZO-White Pigeon to V Drive - EMAT #531243273 92,037 L1200A - KZO-White Pigeon to V Drive - EMAT #6

GL-01743 GL-01768 L3200 - FDM-Vector Leslie to Kinder Morgan29015176 - L3200 - FDM-Vector Leslie to Kinder Morgan - O&M

29059676 212,782 L3200 - FDM-Vector Leslie to Kinder Morgan - Capital31322611 34,853 31099255 (62,571) L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #1

31099256 152,329 L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #231322612 27,841 31099257 37,261 L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #3

31099258 - L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #431322613 44,150 31099259 53,570 L3200 - FDM-Vector Leslie to Kinder Morgan - Dig #5

GL-01744 GL-01769 L2200 - FDM-Chelsea to Fenton29015321 4,777 L2200 - FDM-Chelsea to Fenton - O&M General

29059677 383,468 L2200 - FDM-Chelsea to Fenton - Capital General30962581 34,262 30962387 - L2200 - FDM-Chelsea to Fenton - Dig #1

30962388 50,505 L2200 - FDM-Chelsea to Fenton - Dig #230962582 30962389 58,783 L2200 - FDM-Chelsea to Fenton - Dig #3

30962390 49,711 L2200 - FDM-Chelsea to Fenton - Dig #430962392 44,876 L2200 - FDM-Chelsea to Fenton - Dig #530962393 162,830 L2200 - FDM-Chelsea to Fenton - Dig #6

30962583 35,733 30962394 11,452 L2200 - FDM-Chelsea to Fenton - Dig #730962395 142,905 L2200 - FDM-Chelsea to Fenton - Dig #830962396 135,947 L2200 - FDM-Chelsea to Fenton - Dig #930962397 108,735 L2200 - FDM-Chelsea to Fenton - Dig #1030962398 60,447 L2200 - FDM-Chelsea to Fenton - Dig #11

30962584 90,384 30962399 11,288 L2200 - FDM-Chelsea to Fenton - Dig #12

GL-01745 GL-01770 L2020 - NVL-Pontiac to Decker



Page 24 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09429015323 80,499 L2020 - NVL-Pontiac to Decker - O&M Gen.

29059678 122,979 L2020 - NVL-Pontiac to Decker - Capital Gen.31167144 30410053 - L2020 - NVL-Pontiac to Decker - Dig #1

30410054 78,435 L2020 - NVL-Pontiac to Decker - Dig #230410058 52,908 30410055 - L2020 - NVL-Pontiac to Decker - Dig #3

30410056 94,565 L2020 - NVL-Pontiac to Decker - Dig #4

GL-01746 GL-01771 L3010 - KZO-Olmstead to Galesburg29015327 - Line 3010 -Olmstead to Galesburg - O&M

29059679 151,459 Line 3010 -Olmstead to Galesburg - Capital30855584 105,242 Line 3010 -Olmstead to Galesburg - Dig #130855585 115,072 Line 3010 -Olmstead to Galesburg - Dig #230855587 108,746 Line 3010 -Olmstead to Galesburg - Dig #330855588 90,119 Line 3010 -Olmstead to Galesburg - Dig #430855590 96,467 Line 3010 -Olmstead to Galesburg - Dig #530855592 103,468 Line 3010 -Olmstead to Galesburg - Dig #6

GL-01747 GL-01772 L1100 - KZO-Dorr to Middleville Caledonia29015332 41,049 L1100 - KZO-Dorr to Middleville Caledonia - O&M

29059980 301,087 L1100 - KZO-Dorr to Middleville Caledonia - Cap.30705414 143,453 L1100 - KZO-Dorr to Middleville Caledonia - Dig #130705415 98,558 L1100 - KZO-Dorr to Middleville Caledonia - Dig #230705416 65,627 L1100 - KZO-Dorr to Middleville Caledonia - Dig #330705417 104,242 L1100 - KZO-Dorr to Middleville Caledonia - Dig #4

30705527 67,771 30705418 - L1100 - KZO-Dorr to Middleville Caledonia - Dig #530705528 76,237 30705419 - L1100 - KZO-Dorr to Middleville Caledonia - Dig #6

30705520 114,831 L1100 - KZO-Dorr to Middleville Caledonia - Dig #730705521 171,520 L1100 - KZO-Dorr to Middleville Caledonia - Dig #830705522 631,134 L1100 - KZO-Dorr to Middleville Caledonia - Dig #930705523 66,132 L1100 - KZO-Dorr to Middleville Caledonia - Dig #10

30705529 30705524 113,565 L1100 - KZO-Dorr to Middleville Caledonia - Dig #1130705525 116,915 L1100 - KZO-Dorr to Middleville Caledonia - Dig #12

GL-01748 GL-01773 L100B - SAG-Herrick to Muskegon29015337 145,630 L100B - SAG-Herrick to Muskegon - O&M Gen.

29059981 136,277 L100B - SAG-Herrick to Muskegon - Capital Gen.30977337 30977324 310,195 L100B - SAG-Herrick to Muskegon - Dig #130977338 30977326 151,236 L100B - SAG-Herrick to Muskegon - Dig #230977339 30977327 46,955 L100B - SAG-Herrick to Muskegon - Dig #330977460 26,259 30977328 - L100B - SAG-Herrick to Muskegon - Dig #4



Page 25 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09430977462 29059985 293,867 L100B - SAG-Herrick to Muskegon - Dig #530977463 30977331 - L100B - SAG-Herrick to Muskegon - Dig #630977464 41,909 30977332 - L100B - SAG-Herrick to Muskegon - Dig #730977465 66,690 30977333 - L100B - SAG-Herrick to Muskegon - Dig #830977466 33,466 30977334 - L100B - SAG-Herrick to Muskegon - Dig #9

GL-01749 GL-01774 STC-Ira Mainline 20"29015339 17,456 STC-Ira Mainline 20" O&M - General

29059982 109,589 STC-Ira Mainline 20" Capital - General30705401 33,065 STC-Ira Mainline 20" Capital - Dig #1

30705407 30705402 50,647 STC-Ira Mainline 20" Capital - Dig #230705403 60,641 STC-Ira Mainline 20" Capital - Dig #330705404 73,816 STC-Ira Mainline 20" Capital - Dig #430705405 69,025 STC-Ira Mainline 20" Capital - Dig #5

GL-01750 GL-01775 L600 - STC-Clarkston to Squirrel

29059983 937,798 L600 - STC-Clarkston to Squirrel - General Capital31486828 26,157 L600 - STC-Clarkston to Squirrel - Dig #131486829 31,552 L600 - STC-Clarkston to Squirrel - Dig #231486830 40,518 L600 - STC-Clarkston to Squirrel - Dig #331486831 22,150 L600 - STC-Clarkston to Squirrel - Dig #431486832 - L600 - STC-Clarkston to Squirrel - Dig #531486833 - L600 - STC-Clarkston to Squirrel - Dig #631486834 - L600 - STC-Clarkston to Squirrel - Dig #7

GL-01751 GL-01776 L1600 - NVL-Northville to Coolidge29015547 77,380 L1600 - NVL-Northville to Coolidge - O&M

29059984 669,315 L1600 - NVL-Northville to Coolidge - Capital30704850 129,157 L1600 - NVL-Northville to Coolidge - Dig #130704851 243,479 L1600 - NVL-Northville to Coolidge - Dig #230704852 187,483 L1600 - NVL-Northville to Coolidge - Dig #330704853 143,292 L1600 - NVL-Northville to Coolidge - Dig #430704854 188,836 L1600 - NVL-Northville to Coolidge - Dig #530704855 118,274 L1600 - NVL-Northville to Coolidge - Dig #6

31167037 101,879 30704856 - L1600 - NVL-Northville to Coolidge - Dig #730704857 274,258 L1600 - NVL-Northville to Coolidge - Dig #830704858 324,720 L1600 - NVL-Northville to Coolidge - Dig #930704859 130,187 L1600 - NVL-Northville to Coolidge - Dig #1030704940 154,826 L1600 - NVL-Northville to Coolidge - Dig #11



Page 26 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09430704941 253,735 L1600 - NVL-Northville to Coolidge - Dig #1230704942 126,025 L1600 - NVL-Northville to Coolidge - Dig #1330704943 177,649 L1600 - NVL-Northville to Coolidge - Dig #1430704944 227,650 L1600 - NVL-Northville to Coolidge - Dig #1530704945 121,603 L1600 - NVL-Northville to Coolidge - Dig #1630704946 148,594 L1600 - NVL-Northville to Coolidge - Dig #1730704947 217,720 L1600 - NVL-Northville to Coolidge - Dig #1830704948 241,270 L1600 - NVL-Northville to Coolidge - Dig #19

30704950 36,807 30704949 - L1600 - NVL-Northville to Coolidge - Dig #2030704952 171,039 L1600 - NVL-Northville to Coolidge - Dig #2130704953 208,362 L1600 - NVL-Northville to Coolidge - Dig #2230704954 153,574 L1600 - NVL-Northville to Coolidge - Dig #2330704956 143,193 L1600 - NVL-Northville to Coolidge - Dig #2430704957 270,523 L1600 - NVL-Northville to Coolidge - Dig #2530704958 169,564 L1600 - NVL-Northville to Coolidge - Dig #2630704980 219,498 L1600 - NVL-Northville to Coolidge - Dig #2730704981 140,640 L1600 - NVL-Northville to Coolidge - Dig #2830704982 240,190 L1600 - NVL-Northville to Coolidge - Dig #2930704983 261,136 L1600 - NVL-Northville to Coolidge - Dig #30

31167140 76,591 30704984 - L1600 - NVL-Northville to Coolidge - Dig #3130704985 335,886 L1600 - NVL-Northville to Coolidge - Dig #32

GL-01752 GL-01777 L1060 - STC-St. Clair to Mt. Clemens29015551 51,630 L1060 - STC-St. Clair to Mt. Clemens - O&M

29059985 293,867 L1060 - STC-St. Clair to Mt. Clemens - Capital30414402 186,088 L1060 - STC-St. Clair to Mt. Clemens - Dig #130414404 140,851 L1060 - STC-St. Clair to Mt. Clemens - Dig #230414405 258,017 L1060 - STC-St. Clair to Mt. Clemens - Dig #3

31322617 145,680 30414406 - L1060 - STC-St. Clair to Mt. Clemens - Dig #430414407 317,494 L1060 - STC-St. Clair to Mt. Clemens - Dig #530414408 276,115 L1060 - STC-St. Clair to Mt. Clemens - Dig #630414409 265,999 L1060 - STC-St. Clair to Mt. Clemens - Dig #730414411 96,255 L1060 - STC-St. Clair to Mt. Clemens - Dig #830414412 94,329 L1060 - STC-St. Clair to Mt. Clemens - Dig #930414413 501,643 L1060 - STC-St. Clair to Mt. Clemens - Dig #1030414415 528,662 L1060 - STC-St. Clair to Mt. Clemens - Dig #1130414416 111,393 L1060 - STC-St. Clair to Mt. Clemens - Dig #1230414417 99,577 L1060 - STC-St. Clair to Mt. Clemens - Dig #1330414418 83,655 L1060 - STC-St. Clair to Mt. Clemens - Dig #1430414419 586,049 L1060 - STC-St. Clair to Mt. Clemens - Dig #15



Page 27 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09431322618 28,255 30414460 - L1060 - STC-St. Clair to Mt. Clemens - Dig #16

GL-01753 GL-01778 L1020 - NVL-South Lyon to Northville 29015555 50,046 L1020 - NVL-South Lyon to Northville - O&M

29059986 148,511 L1020 - NVL-South Lyon to Northville - Capital 30081398 30081298 281,245 L1020 - NVL-South Lyon to Northville - Dig #1

30081299 265,412 L1020 - NVL-South Lyon to Northville - Dig #230081321 196,638 L1020 - NVL-South Lyon to Northville - Dig #330081322 167,974 L1020 - NVL-South Lyon to Northville - Dig #4

30081427 129,251 30081324 - L1020 - NVL-South Lyon to Northville - Dig #530081446 30081325 239,783 L1020 - NVL-South Lyon to Northville - Dig #630081449 116,884 30081327 - L1020 - NVL-South Lyon to Northville - Dig #7

GL-01754 GL-01779 L250 - SAG-Mt Pleasant to Zilwaukee30217102 16,091 L250 - SAG-Mt Pleasant to Zilwaukee - O&M Gen.

29059987 375,218 L250 - SAG-Mt Pleasant to Zilwaukee - Capital Gen.30216956 167,998 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #130216957 29,996 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #2

30217103 30216958 137,827 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #330216959 311,751 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #430217080 128,605 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #5

30217104 30217081 92,258 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #630217082 181,827 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #730217083 108,136 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #830217084 108,820 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #9

30217105 30217085 84,755 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1030217106 30217086 96,913 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1130217107 30217087 173,965 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #12

30217088 82,340 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1330217108 30217089 41,513 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1430217109 30217090 91,074 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1530217110 30217091 28,568 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #16

30217092 82,939 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1730217111 30217093 46,806 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1830217112 30217094 156,111 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #1930217113 30217095 81,327 L250 - SAG-Mt Pleasant to Zilwaukee - Dig #2030217115 53,080 30217097 - L250 - SAG-Mt Pleasant to Zilwaukee - MAOP Dig #2230217116 30217098 78,105 L250 - SAG-Mt Pleasant to Zilwaukee - MAOP Dig #2330217117 30217099 81,862 L250 - SAG-Mt Pleasant to Zilwaukee - MAOP Dig #24



Page 28 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 094GL-01755 GL-01780 L1800 - KZO-Schoolcraft to Plainwell29015754 71,334 L1800 - KZO-Schoolcraft to Plainwell - O&M

29059988 257,368 L1800 - KZO-Schoolcraft to Plainwell - Capital30414463 113,235 L1800 - KZO-Schoolcraft to Plainwell - Dig #130414464 134,762 L1800 - KZO-Schoolcraft to Plainwell - Dig #230414465 169,868 L1800 - KZO-Schoolcraft to Plainwell - Dig #330414466 103,933 L1800 - KZO-Schoolcraft to Plainwell - Dig #430414467 59,946 L1800 - KZO-Schoolcraft to Plainwell - Dig #530414468 128,876 L1800 - KZO-Schoolcraft to Plainwell - Dig #630414469 74,028 L1800 - KZO-Schoolcraft to Plainwell - Dig #730414470 69,662 L1800 - KZO-Schoolcraft to Plainwell - Dig #8

30977490 256,620 30414471 - L1800 - KZO-Schoolcraft to Plainwell - Dig #930414477 40,155 30414472 - L1800 - KZO-Schoolcraft to Plainwell - Dig #1030414478 34,699 30414473 - L1800 - KZO-Schoolcraft to Plainwell - Dig #11

30414474 97,370 L1800 - KZO-Schoolcraft to Plainwell - Dig #12

GL-01756 GL-01781 L1800 - KZO-White Pigeon to Schoolcraft29016067 48,533 L1800 - KZO-White Pigeon to Schoolcraft - O&M

29059989 880,694 L1800 - KZO-White Pigeon to Schoolcraft - Capital30146577 156,842 L1800 - KZO-White Pigeon to Schoolcraft - Dig #130146643 141,167 L1800 - KZO-White Pigeon to Schoolcraft - Dig #230146649 127,254 L1800 - KZO-White Pigeon to Schoolcraft - Dig #330146656 160,360 L1800 - KZO-White Pigeon to Schoolcraft - Dig #4

30146767 30146702 101,339 L1800 - KZO-White Pigeon to Schoolcraft - Dig #530146709 158,389 L1800 - KZO-White Pigeon to Schoolcraft - Dig #630146716 2,564,972 L1800 - KZO-White Pigeon to Schoolcraft - Dig #730146724 145,096 L1800 - KZO-White Pigeon to Schoolcraft - Dig #8

30146768 30146731 93,584 L1800 - KZO-White Pigeon to Schoolcraft - Dig #930146734 134,906 L1800 - KZO-White Pigeon to Schoolcraft - Dig #10

30146769 64,526 30146735 - L1800 - KZO-White Pigeon to Schoolcraft - Dig #1130146737 153,728 L1800 - KZO-White Pigeon to Schoolcraft - Dig #12

30146770 30146738 111,585 L1800 - KZO-White Pigeon to Schoolcraft - Dig #1330146739 104,597 L1800 - KZO-White Pigeon to Schoolcraft - Dig #1430146760 115,436 L1800 - KZO-White Pigeon to Schoolcraft - Dig #1530146761 105,414 L1800 - KZO-White Pigeon to Schoolcraft - Dig #1630146762 137,621 L1800 - KZO-White Pigeon to Schoolcraft - Dig #1730146763 147,785 L1800 - KZO-White Pigeon to Schoolcraft - Dig #1830146764 95,265 L1800 - KZO-White Pigeon to Schoolcraft - Dig #19

GL-01757 GL-01782 L1800 - KZO-Plainwell to 30th



Page 29 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09429016623 65,029 L1800 - KZO-Plainwell to 30th - O&M

29059990 396,169 L1800 - KZO-Plainwell to 30th - Capital30120723 30120605 147,381 L1800 - KZO-Plainwell to 30th - Dig #1

30120607 283,362 L1800 - KZO-Plainwell to 30th - Dig #230120724 30120608 126,535 L1800 - KZO-Plainwell to 30th - Dig #3

30120609 99,063 L1800 - KZO-Plainwell to 30th - Dig #430120610 185,089 L1800 - KZO-Plainwell to 30th - Dig #530120611 109,738 L1800 - KZO-Plainwell to 30th - Dig #630120612 82,795 L1800 - KZO-Plainwell to 30th - Dig #730120613 185,784 L1800 - KZO-Plainwell to 30th - Dig #830120614 110,296 L1800 - KZO-Plainwell to 30th - Dig #930120615 119,450 L1800 - KZO-Plainwell to 30th - Dig #1030120616 131,986 L1800 - KZO-Plainwell to 30th - Dig #1130120617 95,457 L1800 - KZO-Plainwell to 30th - Dig #12

30120725 27,222 30120619 - L1800 - KZO-Plainwell to 30th - Dig #1330120726 65,752 30120720 - L1800 - KZO-Plainwell to 30th - Dig #1430120727 159,679 30120721 - L1800 - KZO-Plainwell to 30th - Dig #15

GL-01759 GL-01784 L100C - SAG-Airport to Herrick29016634 186 L100C - SAG-Airport to Herrick - O&M General

29059992 1,016,837 L100C - SAG-Airport to Herrick - Capital General31166470 505,157 L100C - SAG-Airport to Herrick - Dig #131166471 106,465 L100C - SAG-Airport to Herrick - Dig #231166472 266,302 L100C - SAG-Airport to Herrick - Dig #331166473 265,000 L100C - SAG-Airport to Herrick - Dig #431166474 126,677 L100C - SAG-Airport to Herrick - Dig #531166475 92,557 L100C - SAG-Airport to Herrick - Dig #631166476 130,198 L100C - SAG-Airport to Herrick - Dig #731166477 120,372 L100C - SAG-Airport to Herrick - Dig #831166478 114,573 L100C - SAG-Airport to Herrick - Dig #931166479 90,708 L100C - SAG-Airport to Herrick - Dig #1031166520 295,421 L100C - SAG-Airport to Herrick - Dig #1131166521 189,670 L100C - SAG-Airport to Herrick - Dig #1231166522 148,246 L100C - SAG-Airport to Herrick - Dig #1331166523 163,721 L100C - SAG-Airport to Herrick - Dig #1431166524 129,623 L100C - SAG-Airport to Herrick - Dig #1531166525 86,679 L100C - SAG-Airport to Herrick - Dig #1631166526 129,099 L100C - SAG-Airport to Herrick - Dig #1731166527 167,068 L100C - SAG-Airport to Herrick - Dig #1831166528 129,930 L100C - SAG-Airport to Herrick - Dig #19



Page 30 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09431166529 88,534 L100C - SAG-Airport to Herrick - Dig #2031166530 91,634 L100C - SAG-Airport to Herrick - Dig #2131166531 100,128 L100C - SAG-Airport to Herrick - Dig #2231166532 153,161 L100C - SAG-Airport to Herrick - Dig #2331166533 210,771 L100C - SAG-Airport to Herrick - Dig #2431166534 120,438 L100C - SAG-Airport to Herrick - Dig #2531166535 77,819 L100C - SAG-Airport to Herrick - Dig #26

31166567 31166537 92,401 L100C - SAG-Airport to Herrick - Dig #2731166538 142,246 L100C - SAG-Airport to Herrick - Dig #2831166539 161,087 L100C - SAG-Airport to Herrick - Dig #2931166560 127,202 L100C - SAG-Airport to Herrick - Dig #3031166561 138,251 L100C - SAG-Airport to Herrick - Dig #31

31166568 31166562 133,778 L100C - SAG-Airport to Herrick - Dig #3231166563 34,933 L100C - SAG-Airport to Herrick - Dig #4031166564 104,955 L100C - SAG-Airport to Herrick - Dig #4131166565 26,518 L100C - SAG-Airport to Herrick - Dig #4231322604 101,289 L100C - SAG-Airport to Herrick - EMAT #131322605 113,236 L100C - SAG-Airport to Herrick - EMAT #231322606 56,530 L100C - SAG-Airport to Herrick - EMAT #331322607 119,017 L100C - SAG-Airport to Herrick - EMAT #431322608 71,319 L100C - SAG-Airport to Herrick - EMAT #531322610 130,071 L100C - SAG-Airport to Herrick - EMAT #6

GL-01760 GL-01785 L1080 - FDM-Maple Dale to Park Rd29016636 84,075 L1080 - FDM-Maple Dale to Park Rd - O&M

29059993 109,861 L1080 - FDM-Maple Dale to Park Rd - Capital30466435 43,447 - L1080 - FDM-Maple Dale to Park Rd - Dig #130466436 - 30705533 74,382 L1080 - FDM-Maple Dale to Park Rd - Dig #230466437 33,864 - L1080 - FDM-Maple Dale to Park Rd - Dig #330466438 54,924 - L1080 - FDM-Maple Dale to Park Rd - Dig #430466439 33,922 - L1080 - FDM-Maple Dale to Park Rd - Dig #5

30466585 120,053 L1080 - FDM-Maple Dale to Park Rd - Dig #630466580 - 30705534 151,893 L1080 - FDM-Maple Dale to Park Rd - Dig #7

30466587 101,232 L1080 - FDM-Maple Dale to Park Rd - Dig #830466582 40,970 L1080 - FDM-Maple Dale to Park Rd - Dig #9

GL-01762 GL-01787 L2500 - M72 VS to Shell Processing Plant29016761 174,544 L2500 - M72 VS to Shell Processing Plant - O&M

29059995 213,866 L2500 - M72 VS to Shell Processing Plant - Capital30574083 99,695 L2500 - M72 VS to Shell Processing Plant - Dig #1



Page 31 of 31

2017 Actual O&M Expense Capital Expenditure U-18424 MPSC Staff Audit Rqst 09430574098 72,574 30574084 - L2500 - M72 VS to Shell Processing Plant - Dig #2

30574085 85,003 L2500 - M72 VS to Shell Processing Plant - Dig #330574099 35,226 30574086 - L2500 - M72 VS to Shell Processing Plant - Dig #430574140 24,402 30574087 - L2500 - M72 VS to Shell Processing Plant - Dig #5

30574088 89,939 L2500 - M72 VS to Shell Processing Plant - Dig #630574141 41,281 30574089 - L2500 - M72 VS to Shell Processing Plant - Dig #7

30574090 81,401 L2500 - M72 VS to Shell Processing Plant - Dig #830574092 208,197 L2500 - M72 VS to Shell Processing Plant - Dig #9

30574142 100,063 30574093 - L2500 - M72 VS to Shell Processing Plant - Dig #1030574143 54,969 30574094 - L2500 - M72 VS to Shell Processing Plant - Dig #11

30574095 123,885 L2500 - M72 VS to Shell Processing Plant - Dig #1230574144 43,760 30574096 - L2500 - M72 VS to Shell Processing Plant - Dig #13



18424-AG-CE-104

Question:

77. Refer to Exhibit A-62 (MPP-15), page 1. Please:a. Provide the same information for service lines replaced in 2015 and 2016.

b. Explain why the cost per service is 27% higher in 2017 than in 2018 and 2019.

Response:

For purposes of responding to this interrogatory, the Company assumes this question is referring to page 2 of the aforementioned exhibit and not page 1.

a. As described in my direct testimony on page 51, line 2, the Vintage ServiceReplacement Program (VSR) began in 2017, thus there is no information for thisprogram for 2015 and 2016

b. The 2017 unit cost is reflective of the actual unit cost experienced through August of2017. The Company has set an aggressive goal to improve performance goingforward in the program. The projection is based upon measures the Company istaking to improve efficiency in the VSR in 2018 and beyond. The Company was ableto determine several lessons learned from our efforts in 2017 and have implementedchanges to the way we select services for replacement. The Company has alsoidentified some operational changes to implement in 2018 in an attempt to drivedown the cost per service. As the program continues, we will continue to review ouroperations and engineering processes to improve efficiency.



42400127




.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 12/19/2017 NO. CLC-4 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/5/2018 RESPONDENT: Mary P. Palkovich Question: 5. With reference the Material Condition program and the testimony of Company Witness Mary

Palkovich, pages 50-54, identify the average service line replacement cost used for projecting program capital expenditures related to leak remediation through full service line replacement under the Material Condition Non-modeled, Material Condition Renewal, and Vintage Service Replacement programs in this case. If an average cost per service replacement was not used in projecting expenditures, please discuss the methodology used and provide any relevant calculations.

Answer: The expenditures for the Material Condition Non-Model program were projected at the program

level which includes metering, main and service line remediation projects. The 2018 projection is expected to be in line with the 2016 actual amount (plus inflation) with adjustments for a build over at the Bridgeport city gate ($1.9M), a project at the GM powerhouse in Bay City ($.8M) and three standard pressure replacement projects ($2.3M).

The average service line replacement cost used for the Material Condition Renewals program is approximately $5,000 each in 2018 and 2019.

The average service line replacement cost used for the Vintage Service Replacement program as shown on Exhibit A-62 (MPP-15) at page 2 is $3,875 in 2018 and 2019.




MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 12/19/2017 NO. CLC-4 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/5/2018 RESPONDENT: Mary P. Palkovich Question: 4. With reference to the Material Condition program and the testimony of Company Witness Mary

Palkovich, pages 50-54, provide the number of service line replacements completed by program (EIRP, Material Condition Renewals, Material Condition Non-Modeled, and Asset Relocation programs, any other routine programs) for each year 2014, 2015, 2016, and 2017. Additionally, identify the projected number of service leak remediation through full service line replacements and related capital expenditures under the Material Condition Non-Modeled and Material Condition Renewals that were used to determine the capital expenditure level in this current case for 2018 and the 6-month period ending June 30, 2019.

Answer:

The table below shows the number of service replacements by category, as specified above.

The projection in 2018 and 2019 is the replacement of 3,200 services per year in the Material

Condition Renewals program. In the Material Condition Non-Modeled program as described in the response to MPSC Staff Audit #106, the Company projected the expenditures on a total program

5345

2423

3204

0 21 16 2680

9666

3930

1954

2004

0 3 09781

3894

2944

3031

21 36 09359

3216

1960

2551

6 13 0

0

2000

4000

6000

8000

10000

12000

EIR

P

Ass

et R

eloc

atio

n- C

ivic

MC

Non

-M

odel

ed

Mat

eria

lC

ondi

tion

Ren

ewal

s

Reg

Bas

e -

Dis

tribu

tion

Aug

men

t

DIM

P

2014

2015

2016

2017*

* - 2017 Data incomplete (as of Dec 21)




basis which would include metering, mains and service lines and did not project a specific service replacement count for 2018 or 2019.

.




.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 12/19/2017 NO. CLC-4 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/5/2018 RESPONDENT: Mary P. Palkovich Question: 2. With reference to the Material Condition program and the testimony of Company Witness Mary

Palkovich on page 50, the EIRP scope identifies, “Replacement of vintage service materials associated with the main replacement projects.” This language differs from the EIRP scope identified by Company Witness Holly Bowers in her direct testimony on page 44 in Case No. U-18124, and as supported by Staff in that case and approved by Commission order, which states, “Replacement of vintage service materials (copper, Xtrube, bare and pre-1965 steel).” Additionally, on page 51 of the testimony of Company Witness Mary Palkovich, the Vintage Service Replacement (VSR) is described to replace copper and bare steel service lines. Please clarify by providing a list of all service line materials identified and included as a vintage service material to be replaced through the EIRP Distribution, Material Condition Non-Modeled, Material Condition Renewal, and VSR programs in this case. If the vintage service line materials targeted vary between programs, please identify accordingly. Additionally, provide the total number of vintage service lines by material type remaining on the Company’s distribution system as of year-end 2017 that are targeted for replacement as a vintage service line material.

Answer: The VSR is targeted to replace copper and bare steel services and services of unknown material type that are not already identified in planned EIRP high-risk main replacement projects or other planned main replacement projects. The other programs are targeted to replace service lines based upon the material condition and in conjunction with main replacement where construction concerns warrant. Example of material conditions include leaks, third party damage, corrosion or other failure modes. When mains are replaced under EIRP or other Material Condition projects the associated services are replaced unless they are plastic or unless plastic cannot be tied over to the new main due to the proximity or other operational reasons.

Service Line Materials to be Replaced by Program: EIRP mains and associated services. Services replaced would be all types except plastic unless

plastic cannot be tied over to the new main due to the proximity or other operations reasons Material Condition Non-Modeled: Services replaced would be all types except plastic unless

plastic cannot be tied over to the new main due to the proximity or other operations reasons. Material Condition Renewals: services replaced would be all types except plastic unless plastic

cannot be tied over to the new main due to the proximity or other operations reasons. VSR: services replaced would be copper, bare steel and those services for which the material

type is unknown. The chart below shows the total number of service lines by material type on the Company’s system as of January 2, 2018.




.




.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 12/19/2017 NO. CLC-4 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/5/2018 RESPONDENT: Mary P. Palkovich Question: 7. With reference to the Material Condition program and Exhibit A-58 (MPP-11), the Company has

identified capital expenditures of $31.1 million in 2017, $40.7 million in 2018, and $19.5 million in the 6-month period ending June 30, 2019. In the rebuttal testimony in Case No. U-18124 of Company Witness Holly Bowers on page 10, the average spend for the scope of work that is included in the VSR in this case was identified as $15 million. Please explain the reasoning for the substantial increase in spending on this program and why it is necessary and prudent to implement the program at that level.

Answer:

The VSR projected in this filing is a program to eliminate copper and bare steel services from the Company system within 10 years. The $15 million projected in Case No. U-18124 was an annual increase to the EIRP program to replace certain service material types but would not have replaced these service types in a 10 year period. The Commission’s order in Case No. U-18124, while supportive of the inclusion of vintage service replacements in the EIRP, did not include incremental funding for service replacements. The Company believes it would be beneficial to customers to have a separate vintage service replacement program outside of the EIRP and has proposed the VSR in this docket. It is necessary and prudent to implement the VSR on an accelerated timeframe in order to replace copper and bare steel services, which have a high leak rate percentage, in order to improve public safety and customer reliability.




.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 12/19/2017 NO. CLC-4 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/5/2018 RESPONDENT: Mary P. Palkovich Question: 6. With reference to the Vintage Service Replacement (VSR) program and the testimony of Company

Witness Mary Palkovich on page 51, clarify if any of the vintage service line replacement through this program is intended to include service lines attached to high-risk main that is targeted for replacement through the EIRP distribution program. Additionally after the completion of the 10-year VSR program, does the Company anticipate that there will be any inventory of identified service line materials remaining on its distribution system that will be targeted for full service line replacement through EIRP Distribution, Material Condition Non-Modeled, or Material Condition Renewal programs? In what year does the Company project that all vintage service lines currently identified (as requested in audit CLC-4, question 2) will be eliminated?

Answer:

Service lines that are not plastic are replaced in conjunction with EIRP main replacement projects. The VSR is only targeting copper, bare steel and services of unknown material type that are not already identified in planned EIRP high-risk main replacement projects or other planned main replacement projects. Those service types will be eliminated after the 10 year program is complete. Copper and bare steel were selected as the first vintage service materials to eliminate due to their higher leak rate, consistent with distribution integrity management principles. After the 10 year VSR program is complete, all copper, bare steel and service lines of unknown material type will have been replaced. After the 10 year VSR program is complete, there will remain service materials other than plastic that will continue to be replaced as part of EIRP or other Material Condition programs that involve main replacements or as a result of leaks. For example, there will still be non-plastic service materials (such as coated and wrapped steel) on the Company system. The Company does not have a time frame as to when all non-plastic services would be eliminated.



18424-AG-CE-73

Question:

46. Refer to page 52, lines 9-22, of Ms. Palkovich’s direct testimony. Please:a. Provide a full description of the VSR program, including any reports and

presentations made to management seeking approval to initiate this program.b. Provide the number of services to be replaced and related costs of the VSR program

by year from start to completion of the program in Excel. Explain why and how theCompany chose this pace of replacement.

c. Explain why the Company decided to initiate the VSR in 2017 and why it isnecessary to undertake this program at this time.

d. Provide any cost/benefit analysis that the Company has performed to justify thisprogram in Excel with all formulas intact and supporting data.

Response:

a. A full description of the VSR program is included on page 51, line 1 through page 52,line 13 of my direct testimony. Senior management is supportive of the VSR and it isbeing conducted due to the high leak percentage to improve safety and reliability.Additionally, the MPSC Staff has been supportive of a Vintage Service Replacementprogram in prior Company rate case filings.

b. Exhibit A-62 (MPP-15) provides number of services and related costs through the testyear. The attachment entitled 18424-AG-CE-73b contains the number of servicestargeted annually through completion of the program. The Company plans to replacethe number of services shown on the attachment each year through the VSR, inaddition to services replaced through other programs, until these service types areeliminated which is projected to be in 10 years. The cost per service can be expectedto increase due to inflationary pressures over time. The Company’s annual targets arebased upon accelerating the pace of removal of these types of services, resourceavailability and to keep the program cost at a stable level.

c. Vintage gas service lines are more prone to leaks, which can pose a safety risk (e.g.rupture, fire, property damage) for our customers and the public. This is due to thefact that vintage services are deteriorating at a rate that is causing increasing leaks onthe gas distribution system. Leaks have the potential to increase public safety andbusiness risk, along with increased emergent work. Services account for 75-80% ofthe leaks found each year. At the current rate, it is estimated that the copper servicesare on a 53 year replacement time frame and bare steel is on a 36 year replacementtimeframe. As a result, the Company needs to replace vintage services at an expeditedrate.


42400121



d. The Company has not performed a cost/benefit ratio. The VSR is being conductedfor public safety and reliability purposes.




42400122



18424-AG-CE-73b Attachment

Vintage Service Replacement Program

Year 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026Vintage Service Replacemnt Program $(000) $31,080 $40,688 $48,438 $66,204 $67,528 $68,879 $70,257 $71,662 $73,095 $74,557

Cost Per Service 4,933 3,875 3,875 3,953 4,032 4,112 4,194 4,278 4,364 4,451 Number of Services 6,300 10,500 12,500 16,750 16,750 16,750 16,750 16,750 16,750 16,750



NOTICE: This report is required by 49 CFR Part 191. Failure to report can result in a civil penalty not to exceed 100,000 for each violation for each day that such violation persists except that the maximum civil penalty shall not exceed $1,000,000 as provided in 49 USC 60122.

OMB NO: 2137-0629EXPIRATION DATE: 5/31/2018

U.S Department of Transportation Pipeline and Hazardous Materials Safety Administration

Initial DateSubmitted:

03/09/2017

Form Type: INITIAL

Date Submitted:

ANNUAL REPORT FORCALENDAR YEAR 2016

GAS DISTRIBUTION SYSTEMA federal agency may not conduct or sponsor, and a person is not required to respond to, nor shall a person be subject to a penalty for failure to comply with a collection of information subject to the requirements of the Paperwork Reduction Act unless that collection of information displays a current valid OMB Control Number. The OMB Control Number for this information collection is 2137-0629. Public reporting for this collection of information is estimated to be approximately 16 hours per response, including the time for reviewing instructions, gathering the data needed, and completing and reviewing the collection of information. All responses to this collection of information are mandatory. Send comments regarding this burden estimate or any other aspect of this collection of information, including suggestions for reducing this burden to: Information Collection Clearance Officer, PHMSA, Office of Pipeline Safety (PHP-30) 1200 New Jersey Avenue, SE, Washington, D.C. 20590.


PART A - OPERATOR INFORMATION (DOT use only) 20176855-31439

1. Name of Operator CONSUMERS ENERGY CO

2. LOCATION OF OFFICE (WHERE ADDITIONAL INFORMATION MAY BE OBTAINED)

2a. Street Address 1945 W Parnall Rd

2b. City and County Jackson

2c. State MI

2d. Zip Code 49201

3. OPERATOR'S 5 DIGIT IDENTIFICATION NUMBER 2748

4. HEADQUARTERS NAME & ADDRESS

4a. Street Address ONE ENERGY PLAZA

4b. City and County JACKSON

4c. State MI

4d. Zip Code 49201

5. STATE IN WHICH SYSTEM OPERATES MI

6. THIS REPORT PERTAINS TO THE FOLLOWING COMMODITY GROUP (Select Commodity Group based on the predominant gas carried and complete the report for that Commodity Group. File a separate report for each Commodity Group included in this OPID.)

Natural Gas

7. THIS REPORT PERTAINS TO THE FOLLOWING TYPE OF OPERATOR (Select Type of Operator based on the structure of the company included in this OPID for which this report is being submitted.):

Investor Owned

PART B - SYSTEM DESCRIPTION

1.GENERAL

STEEL

PLASTICCAST/

WROUGHTIRON

DUCTILEIRON COPPER OTHER

RECONDITIONED

CAST IRON

SYSTEMTOTAL

UNPROTECTEDCATHODICALLY

PROTECTED

BARE COATED BARE COATED

MILES OF MAIN 176.498 333.704 698.680

11831.226 13777.102 479.032 0 0.295 5.011 0 27301.548

NO. OF SERVICES 1503 19818 11343 340656 1021759 0 0 160242 11384 0 1566705





2.MILES OF MAINS IN SYSTEM AT END OF YEAR

MATERIAL UNKNOWN 2" OR LESS OVER 2"THRU 4"

OVER 4"THRU 8"

OVER 8"THRU 12" OVER 12" SYSTEM

TOTALS

STEEL 0 6928.742 2551.036 3390.328 153.985 16.017 13040.108

DUCTILE IRON 0 0 0 0 0 0 0

COPPER 0 0.295 0 0 0 0 .295

CAST/WROUGHT IRON

0 16.988 256.149 168.547 34.707 2.642 479.033

PLASTIC PVC 0 0 0 0 0 0 0

PLASTIC PE 0.003 10816.653 2220.773 739.672 0 0 13777.101

PLASTIC ABS 0 0 0 0 0 0 0

PLASTIC OTHER 0 0 0 0 0 0 0

OTHER 0 3.851 1.124 .036 0 0 5.011

RECONDITIONED CAST IRON

0 0 0 0 0 0 0

TOTAL .003 17766.529 5029.082 4298.583 188.692 18.659 27301.548

Describe Other Material: Unknown Material Type

3.NUMBER OF SERVICES IN SYSTEM AT END OF YEAR AVERAGE SERVICE LENGTH: 80


OVER 2"THRU 4"


TOTALS

STEEL 37 341466 30698 970 145 4 373320


COPPER 17 143761 16463 1 0 0 160242

CAST/WROUGHT IRON

0 0 0 0 0 0 0


PLASTIC PE 53 898392 122647 633 34 1 1021760



OTHER 6902 2948 1523 10 1 0 11384


0 0 0 0 0 0 0

TOTAL 7009 1386567 171331 1614 180 5 1566706


4.MILES OF MAIN AND NUMBER OF SERVICES BY DECADE OF INSTALLATION

UNKNOWN PRE-1940

1940-1949 1950-1959 1960-1969 1970-1979 1980-1989 1990-1999 2000-2009 2010-2019 TOTAL



MILES OF MAIN

108.697 669.294 486.163 3021.156 7639.770 2742.471 2268.052 5260.529 3277.506 1827.909 27301.547

NUMBER OF

SERVICES16915 4475 15964 146020 286452 280208 197851 291334 217120 110369 1566708

PART C - TOTAL LEAKS AND HAZARDOUS LEAKS ELIMINATED/REPAIRED DURING THE YEAR

CAUSE OF LEAK MAINS SERVICES

TOTAL HAZARDOUS TOTAL HAZARDOUS

CORROSION FAILURE 260 93 1228 850

NATURAL FORCE DAMAGE 88 44 666 379

EXCAVATION DAMAGE 287 287 1757 1757

OTHER OUTSIDE FORCE DAMAGE

8 8 47 38

PIPE, WELD OR JOINT FAILURE 2 1 11 9

EQUIPMENT FAILURE 122 32 1646 863

INCORRECT OPERATIONS 30 17 45 30

OTHER CAUSE 136 52 1861 951

NUMBER OF KNOWN SYSTEM LEAKS AT END OF YEAR SCHEDULED FOR REPAIR : 2700

PART D - EXCAVATION DAMAGE PART E-EXCESS FLOW VALUE(EFV) DATA

1. TOTAL NUMBER OF EXCAVATION DAMAGES BY APPARENT ROOT CAUSE: 2139

NUMBER OF EFV'S INSTALLED THIS CALENDER YEAR ON SINGLE FAMILY RESIDENTIAL SERVICES: 2005

a. One-Call Notification Practices Not Sufficient: 661

b. Locating Practices Not Sufficient: 252

c. Excavation Practices Not Sufficient: 1034

d. Other: 192

ESTIMATED NUMBER OF EFV'S IN THE SYSTEM AT THE END OF YEAR: 305847

2. NUMBER OF EXCAVATION TICKETS : 414757

PART F - LEAKS ON FEDERAL LAND PART G-PERCENT OF UNACCOUNTED FOR GAS

TOTAL NUMBER OF LEAKS ON FEDERAL LAND REPAIRED OR SCHEDULED TO REPAIR: 42

UNACCOUUNTED FOR GAS AS A PERCENT OF TOTAL INPUT FOR THE 12 MONTHS ENDING JUNE 30 OF THE REPORTING YEAR.

INPUT FOR YEAR ENDING 6/30: 0.21%

PART H - ADDITIONAL INFORMATION

PART I - PREPARER



Amanda Ward,Gas Regulatory Services Sr Eng(Preparer's Name and Title)

(517)545-8746(Area Code and Telephone Number)

[email protected](Preparer's email address) (Area Code and Facsimile Number)



Exhibit No.: S-11.25Witness: C. Creisher

Page: 1 of 1

CAUSE OF LEAK

Replace Repair Replace Repair Replace Repair Replace Repair Replace Repair Replace Repair Replace Repair

CORROSION FAILURE

NATURAL FORCE DAMAGE

EXCAVATION DAMAGE


PIPE, WELD OR JOINT FAILURE

EQUIPMENT FAILURE

INCORRECT OPERATIONS

OTHER CAUSE

Unknown Xtrube (Add identified material types as necessary)

Copper Bare steel, unprotected Bare steel, protected Coated steel, unprotected

Case No.: U-18424Exhibit No.: S-11.26

Witness: C. CreisherPage: 1 of 1

Pipe TypeSystem Miles at beginning of

Program YearMiles replaced in Program Year under EIRP program

Miles replaced in Program Year under non-EIRP program1

System Miles remaining at end of Program Year

Cast ironBare steelCoated and wrappedThreaded and coupledWrought ironX-trubeCopperTotal

Code 33Miles remaining as of beginning of

Program YearBare Steel 201.4Coated and wrapped 314.2Total 515.6

Notes:1. Miles of EIRP pipe type that were replaced as part of other programs like Civic Improvement or Emergent .2. Coated and wrapped pipe replaced as part of EIRP projects due to the configuration of the system, project constructabilityor code 3 condition but not an EIRP targeted pipe type.3. Code 3 cathodically unprotected against corrosion.coated and wrapped pipe. The 2016 EIRP projects will replace 17.2 miles of Code 3 pipe in a combination of bare and coated and wrapped steel.


.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 01/31/2018 NO. CLC-13 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 2/9/2018 RESPONDENT: Mary P. Palkovich Question: 1. With reference to Discovery responses 18424-AG-CE-104 and 18424-AG-CE-358 and Company

Exhibit A-62 (MPP-15), page 2, regarding service line replacement costs: a. Discuss why the Vintage Service Replacement program is experiencing and projected to

continue experiencing service line replacement unit costs significantly higher than the average service line replacement costs for 2015, 2016, and 2017 as referenced in 18424-AG-CE-358.

b. Provide the updated number of service line replacements completed under the VSR in 2017 and the associated cost per service.

c. Identify the amount of main replaced as part of the VSR in 2017. Provide a list of locations and length of main replaced, including justification of why the main replacement was necessary for a service line only replacement project

d. Identify and quantify any additional capital expenditures beyond the actual service (or main) replacement costs that are included in the VSR, such as but not limited to any vehicle, equipment, tool, or other purchases related to the startup of the VSR program.

Answer:

a. There are many reasons why the cost per service replacement is higher in the VSR program than the average service replacement cost. Unit costs in the VSR are higher than services in Asset Relocation, Material Condition Non-Modeled, and EIRP programs as the Company is not replacing every service on the street, as is typically done as part of those programs. VSR projects involve replacing one or two services, then skipping a house or two, then replacing a couple more services, etc. This is less efficient than replacing a gas main and every service along the main. Adding to the complexity is the fact that when new main is installed, the new main is usually not under pavement so tying the new services in is easier and with fewer road breaks, which take additional time. Additionally, the service tee is not retired when tying in to new gas main because the old service is retired. Further, copper services, which comprise the majority of vintage services thus far, are more time consuming to expose due to changes in direction and elevation. This compares to other programs where the new service is attached to new plastic main of known depth. Finally, vintage services are primarily connected to steel main of varying depths which takes longer to expose safely and a welder is used to pin every tee retired.

b. In 2017, the Company replaced 6,242 vintage services through the VSR program. c. There was no main replaced as part of the VSR program in 2017. d. There were no charges in the VSR program for vehicle, equipment, tools, or other purchases

related to the startup of the program. All charges were related to the replacement of services.



18424-AG-CE-358 (Revised)

Question:

257. Refer to the response to AG-CE-104. Please provide the average cost to replace a service line in each year 2015, 2016 and 2017. Explain why these costs would be or would not be representative of the cost to replace a service line under the VSR program.

Response:

The average cost to replace a service line in 2015 was $2,002; in 2016 was $3,163; and in 2017 was $3,940. Service lines are replaced under several programs including Asset Relocation Decision Analysis Mains and Service, Asset Relocation Non-Modeled, EIRP, Material Condition Non-Modeled, Material Condition Renewals and Vintage Service Replacements. The cost would vary for each program as some programs involve the main replacement along with service replacements, some involve replacements on an emergent basis and others are planned replacements of just the service primarily in close proximity.

___________________________ Mary P. Palkovich February 6, 2018


42400661



18424-AG-CE-358

Question:

257. Refer to the response to AG-CE-104. Please provide the average cost to replace a service line in each year 2015, 2016 and 2017. Explain why these costs would be or would not be representative of the cost to replace a service line under the VSR program.

Response:

The average cost to replace a service line in 2015 was $2,002; in 2016 was $3,163; and in 2017 was $3,226. Service lines are replaced under several programs including Asset Relocation Decision Analysis Mains and Service, Asset Relocation Non-Modeled, EIRP, Material Condition Non-Modeled, Material Condition Renewals and Vintage Service Replacements. The cost would vary for each program as some programs involve the main replacement along with service replacements, some involve replacements on an emergent basis and others are planned replacements of just the service primarily in close proximity.

___________________________ Mary P. Palkovich January 26, 2018


42400634



18424-AG-CE-75

Question:

48. Refer to page 54, lines 1-5, of Ms. Palkovich’s direct testimony. Please:a. Provide and explain the criteria used by field personnel to make a decision as to

whether to renew the facility or repair it.b. Explain what level of management approves the decision.

Response: a. The Company’s goal is to renew the majority of below grade immediate action

(hazardous) and scheduled action (Grade 2) leaks found on metallic services.Renewing these services provides customer value by increasing the safety and gassystem integrity. In some cases, the Company may decide to repair instead of replaceto minimize customer impacts, or due to construction difficulties or other operationalconsiderations at the time of the immediate leak. Additionally, this reduces thechances of leaks in the future with the metallic service line completely replaced.Attached is the Repair/Replace guideline utilized by field personnel to determinewhether to renew or repair the service.

b. Field crews utilize the attached guidelines and/or communicate with field leaders tomake the decision to replace versus repair a leaking service line.



(NOTE: Attached is numbered document 42400096.)

42400095




.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 12/20/2017 NO. CLC-8 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 01/05/2018 RESPONDENT: Christopher T. Fultz Question: 1. With reference to the testimony of Company Witness Christopher Fultz and Exhibit A-26 (CTF-1)

regarding the TED-I Gas Transmission Pipeline and Freedom and St. Clair upgrades, please provide actual project expenditures through 2017 (from beginning of project) for each project detailed on Exhibit A-26, in detail and format consistent with the breakdown as required for segment construction detail in U-18166 (reference U-18166, Exhibit S-7 and document filed in docket U-18166 on December 1, 2017, page 2) as follows:

a. Survey b. Permitting c. Legal d. Real Estate e. Right of way & Easement f. Materials – pipe g. Materials – other h. Engineering and Design i. Construction j. Environmental k. Lab Services l. Misc Other Services m. Admin & General Overhead

Please include in this response a discussion of the discrepancies between the 2018 Construction Expected Cost Breakdown provided in Case No. U-18166 on December 1, 2017 and the projected expenditures as filed in this case on Exhibit A-26. Specifically, please clarify if the document filed in Case No. U-18166 pertains to the Line 2800 – Zilwaukee to Evon Road Valve Site – 18.5 miles of 24” Pipe Installation, or if the 2018 construction breakdown includes expenditures related to other designated phases of construction. Identify if any projected expenditures for the 12 months ending 12/31/2018 require updates based on the December 1, 2017 filing.

Answer:

Costs incurred through 2017 on the TED-I pipeline, Freedom Compressor Station Upgrade, and St. Clair Compressor Station Upgrade projects included in my direct testimony and Exhibit A-26 (CTF-1) are shown below with costs broken out per the categories listed in the audit question. Note the costs listed are through November 2017, as December 2017 actual costs were not available at the time of this response. Also, note there were no costs incurred through 2017 for project “GL-04506 SAG - Line 2800 - Grand Blanc Junction to Wardlow Valve Site - 20.03 Miles of 24" Pipe Installation”.




.

The 2018 Construction Expected Cost Breakdown provided in Case No. U-18166 on December 1, 2017 does pertain only to the Line 2800 – Zilwaukee to Evon Road Valve Site – 18.5 miles of 24” Pipe Installation. The costs shown in the U-18166 filing on December 1, 2017 represent the most recent projection for the 2018 project expenditures. The Company is not updating its rate case projections at this time.

GL-01506SAG - Line 2800 - Evon to Clio Miles of 24" Pipe Installation

Project to date A. Survey $ 411,003 B. Permitting $ 2,938,945 C. Legal $ 5,063 D. Real Estate $ 3,344,983 E. Right of Way & Easement $ 1,892,511 F. Materials - pipe $ 7,768,010 G. Materials - other $ 924,334 H. Engineering & Design $ 3,399,293 I. Construction $ 71,832,416 J. Environmental $ 1,029,455 K Lab Services $ 1,459,184 L. Misc Other Services $ 1,054,122 M. Admin & General Overhead $ 2,711,814

Total $ 98,771,133

COR $ 2,963,134

Total CAP (No COR) $ 95,807,999




.

GL-02506 SAG - Line 2800 - Zilwaukee Junction to Evon Road Valve Site - 18.5 Miles of 24"Pipe Installation

Project to date

A. Survey $ 296,426 B. Permitting $ 50 C. Legal $ 171,639 D. Real Estate $ 1,833,545 E. Right of Way & Easement $ 1,113,425 F. Materials - pipe $ 7,527,860 G. Materials - other $ 172,038 H. Engineering & Design $ 640,031 I. Construction $ 1,052,699 J. Environmental $ 157,167 K Lab Services $ 28,103 L. Misc Other Services $ 41,894 M. Admin & General Overhead $ 857,782

Total $ 13,892,659

COR $ 416,780





.

GL-03506 SAG - Line 2800 - Clio City Gate to Grand Blanc Junction – 29.18 Miles of 24" Pipe Installation

Project to date A. Survey $ 320,550 B. Permitting $ - C. Legal $ - D. Real Estate $ 903,368 E. Right of Way & Easement $ 418,182 F. Materials - pipe $ 4,684,935 G. Materials - other $ 389,961 H. Engineering & Design $ 581,830 I. Construction $ 112,308 J. Environmental $ 110,741 K Lab Services $ - L. Misc Other Services $ 6,203 M. Admin & General Overhead $ 326,461

Total $ 7,854,539

COR $ 235,636





.

GL-01629 FDM - Line 100A - Ovid Valve Site to Williamston City Gate – 25.15 Miles of 36" Pipe Installation

Project to date

A. Survey $ 346,362 B. Permitting $ - C. Legal $ - D. Real Estate $ 344,632 E. Right of Way & Easement $ 48,288 F. Materials - pipe $ - G. Materials - other $ 5,289 H. Engineering & Design $ 933,197 I. Construction $ 192,832 J. Environmental $ 139,459 K Lab Services $ - L. Misc Other Services $ 861,603 M. Admin & General Overhead $ 102,800

Total $ 2,974,461

COR $ 89,234





.

GL- 02629 FDM - Line 100A - Williamston City Gate to Chelsea Interchange – 29.7 Miles of36" Pipe Installation

Project to date

A. Survey $ - B. Permitting $ - C. Legal $ - D. Real Estate $ - E. Right of Way & Easement $ - F. Materials - pipe $ - G. Materials - other $ 2,321 H. Engineering & Design $ 171,962 I. Construction $ - J. Environmental $ - K Lab Services $ - L. Misc Other Services $ - M. Admin & General Overhead $ 20,605

Total $ 194,889

COR $ 5,847

Total CAP (No COR) $ 189,042




.

St. Clair Compressor Station Upgrade

Project to date

A. Survey $ 211,727

B. Permitting $ -

C. Legal $ -

D. Real Estate $ -

E. Right of Way & Easement $ -

F. Materials - pipe $ 3,451,408

G. Materials - other $ 36,679,499

H. Engineering & Design $ 15,709,807

I. Construction $ 93,063,437

J. Environmental $ 72,941

K Lab Services $ 515,454

L. Misc Other Services $ 3,555,876

M. Admin & General Overhead $ 29,476,198

Total $ 182,736,347

COR** $ -


** This project is installing new equipment for the upgrade of the St. Clair Compressor Station. Any equipment removals and/or retirements will occur under a separate Cost of Removal project.




.

Freedom Compressor Station Upgrade

Project to date

A. Survey $ 15,000

B. Permitting $ 15,000

C. Legal $ -

D. Real Estate $ -

E. Right of Way & Easement $ -

F. Materials - pipe $ 625,631

G. Materials - other $ 14,326,160

H. Engineering & Design $ 9,761,247

I. Construction $ 11,489,905

J. Environmental $ 89,925

K Lab Services $ 485

L. Misc Other Services $ 45,946

M. Admin & General Overhead $ 11,551,556

Total $ 47,920,225

COR** $ -


** This project is installing new equipment for the upgrade of the Freedom Compressor Station. There are no equipment removals and/or retirements planned on this project.



MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 01/17/2018 NO. CLC-9 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/29/2018 RESPONDENT: Christopher R. Fultz Question: 1. With reference to Audit Response #124, please amend the response provided to include (in Excel

format) a breakdown of the expenditures by year with the 2017 actual expenditures by month through November and the projected expenditures for December 2017. Supplement the response with December 2017 actual expenditures when available. Additionally, for the St. Clair Compressor Station Upgrade, identify and detail any projected expenditures that will be included in 2018 for the completion of this project.

Include 2018 and 6 months ending June 30, 2019 projections in the amended response.

Answer:

The Excel file CLC-9 has been updated to include a breakdown of the expenditures by year. 2017 spend is broken down by month, with actuals through December. The St. Clair Compressor Station Upgrade includes projected spend in 2018 to complete the project. Further, the CLC-9 file has been updated to include projected spend for each project in 2018 and the 6 months ending June 30, 2019. Note that an additional category was added to show the level of projected Contingency for future spend in 2018 and the 6 months ending June 30, 2019.



Project Description GL-01506SAG - Line 2800 - Evon to Clio Miles of 24" Pipe Installation2013 2014 2015 2016 Jan-17 Feb-17 Mar-17 Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 2018 Jan-June 2019

A. Survey - - - - - - - - 744 30,161 - - 863 377,885 1,350 816 - - B. Permitting - - - 62,715 - 371 385,000 5,152 107 3,580 10,976 2,482,934 18,075 35,424 (65,389) - - - C. Legal - - - - - - - - - - - - - - 5,063 - - - D. Real Estate - - - 1,879,001 788,050 452,285 184,826 318,533 332,415 187,683 133,247 93,799 112,511 189,386 (1,326,751) 63,165 453,357 - E. Right of Way & Easement - - - 385,355 (508,864) 440,071 174,180 (5,585) 5,795 4,014 5,000 2,000 30,336 2,820 1,357,388 311 225,000 - F. Materials - pipe - - - - 20,000 (12,183) 151,741 473,827 5,922,371 1,178,234 4,194 525,467 (495,642) - - - G. Materials - other - - - 54,653 61,178 84,787 30,344 309,080 238,165 170,128 (194,689) 47,479 50,973 56,133 16,106 26,632 - - H. Engineering & Design - - - 702,242 308,347 56,016 232,152 195,662 170,030 182,303 282,277 535,315 473,014 149,960 111,975 54,684 45,000 - I. Construction - - - 2,896,824 3,052,253 134,158 1,957,220 2,584,804 6,330,305 8,745,801 10,506,345 14,695,162 11,422,596 6,700,098 2,806,852 2,419,518 1,800,000 - J. Environmental - - - 882,364 12,034 90,469 (10,110) 36,183 256,544 (20,148) 33,003 22,686 37,966 (344,014) 32,476 59,053 - - K Lab Services - - - 3,880 86,787 (544) 16,234 23,080 101,401 402,207 351,342 372,527 84,974 17,296 19,956 - - L. Misc Other Services - - - 151,533 4,263 9,963 18,692 27,098 56,822 194,227 90,304 47,159 27,272 251,103 175,687 96,709 - -

M. Admin & General Overhead - - - 337,736 74,954 215,794 176,264 191,311 336,148 175,109 149,787 339,794 231,886 242,368 240,664 311,080 626,643 - N. Contingency - - - - - - - - - - - - - - - - 350,000 -

Total - - - 7,352,423 3,816,094 1,558,518 3,299,764 4,152,299 13,672,527 10,952,494 11,422,648 19,143,137 12,778,017 7,746,137 2,877,074 3,051,924 3,500,000 - COR - - - 220,573 114,483 46,756 98,993 124,569 410,176 328,575 342,679 574,294 383,341 232,384 86,312 91,558 105,000 - Total CAP (No COR) - - - 7,131,850 3,701,612 1,511,762 3,200,771 4,027,730 13,262,351 10,623,919 11,079,969 18,568,843 12,394,677 7,513,753 2,790,762 2,960,366 3,395,000 -

Project Description GL-02506 SAG - Line 2800 - Zilwaukee Junction to Evon Road Valve Site - 18.5 Miles of 24"Pipe Installation2013 2014 2015 2016 Jan-17 Feb-17 Mar-17 Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 2018 Jan-June 2019

A. Survey - - - - - - 1,054 74,839 72,130 79,856 95,567 (48,730) 33,387 (14,849) 3,172 3,238 140,000 - B. Permitting - - - - - - - - - - - - 50 - - - 70,000 - C. Legal - - - - - - - - - - - - 79,780 - 91,859 - 255,000 - D. Real Estate - - - - - - 4,990 14,574 93,578 320,696 252,948 425,679 211,075 154,593 355,413 89,208 888,000 - E. Right of Way & Easement - - - - - - - - - 175,973 92,631 210,030 270,968 317,126 46,697 (36,776) 800,000 - F. Materials - pipe - - - - - - - - - 7,441,491 (520,904) 520,904 (39,300) 45,286 80,383 - 836,000 - G. Materials - other - - - - - - - - - - 45 31,437 178,616 (38,061) (0) 10,775 3,290,000 - H. Engineering & Design - - - - - - - - - 216,755 60,000 38,359 134,986 42,187 147,744 44,198 1,317,000 88,000 I. Construction - - - - - - 42,500 (1,555) 8,333 12,000 13,037 11,681 644,826 302,481 19,396 1,906 73,076,000 1,117,000 J. Environmental - - - - - - - - 37 186 4,970 5,617 90,467 55,889 6,594 333,000 - K Lab Services - - - - - - - - - - - - 28,103 - - - 1,755,000 - L. Misc Other Services - - - - - - - - - - - - 55,977 (14,083) - - 4,278,000 -

M. Admin & General Overhead - - - - - - 11,211 81,461 68,185 249,756 19,870 142,271 67,180 152,030 65,819 101,403 2,738,000 88,000 N. Contingency - - - - - - - - - - - - - - - - 10,142,000 323,000

Total - - - - - - 59,755 169,319 242,264 8,496,712 13,194 1,336,600 1,671,266 1,037,178 866,371 220,546 99,918,000 1,616,000 COR - - - - - - 1,793 5,080 7,268 254,901 396 40,098 50,138 31,115 25,991 6,616 2,997,540 48,480 Total CAP (No COR) - - - - - - 57,962 164,239 234,996 8,241,811 12,798 1,296,502 1,621,128 1,006,063 840,380 213,930 96,920,460 1,567,520

Project Description GL-03506 SAG - Line 2800 - Clio City Gate to Grand Blanc Junction – 29.18 Miles of 24" Pipe Installation2013 2014 2015 2016 Jan-17 Feb-17 Mar-17 Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 2018 Jan-June 2019

A. Survey - - - - - 163 5,942 5,619 38,786 37,249 107,243 43,231 98,415 (43,830) 27,732 26,100 200,000 2,000 B. Permitting - - - - - - - - - - - - - - - - 12,000 100,000 C. Legal - - - - - - - - - - - - - - - - 504,800 230,400 D. Real Estate - - - - - 56 592 202,337 (151,129) 657 50,204 348,493 88,658 229,314 134,186 157,245 1,242,882 1,049,118 E. Right of Way & Easement - - - - - - - - - - 9,216 162,924 99,591 97,817 48,634 59,137 8,409,600 1,428,187 F. Materials - pipe - - - - - - - - - 4,320,087 (302,406) 302,407 (125,435) - 490,282 - - 6,680,000 G. Materials - other - - - - 495 34,740 - 28,282 23,793 323,397 (26,304) 24,993 3,489 (23,136) 212 212 4,396,000 70,560 H. Engineering & Design - - - - - - - - - 206,146 40,000 119,274 49,042 82,440 84,929 61,329 520,000 480,000 I. Construction - - - - - - - 38,938 8,334 12,500 9,188 11,682 8,333 13,696 9,637 1,666 2,678,053 28,329,440 J. Environmental - - - - - - - - - - - - 21,829 66,025 22,886 3,168 - 154,950 K Lab Services - - - - - - - - - - - - - - - - 149,120 826,637 L. Misc Other Services - - - - - - - - - - - - 5,635 568 - (49) - 471,117

M. Admin & General Overhead - - - - 104 8,372 1,438 72,566 22,671 85,836 (17,827) 80,372 22,546 24,396 25,988 34,388 815,546 4,453,200 N. Contingency - - - - - - - - - - - - - - - - 4,732,000 11,068,402

Total - - - - 599 43,331 7,972 347,743 (57,546) 4,985,872 (130,686) 1,093,374 272,102 447,292 844,487 343,197 23,660,001 55,344,011 COR - - - - 18 1,300 239 10,432 (1,726) 149,576 (3,921) 32,801 8,163 13,419 25,335 10,296 709,800 1,660,320 Total CAP (No COR) - - - - 581 42,031 7,733 337,311 (55,819) 4,836,295 (126,766) 1,060,573 263,939 433,873 819,152 332,901 22,950,201 53,683,691



Project Description GL-01629 FDM - Line 100A - Ovid Valve Site to Williamston City Gate – 25.15 Miles of 36" Pipe Installation2013 2014 2015 2016 Jan-17 Feb-17 Mar-17 Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 2018 Jan-June 2019

A. Survey - - - 291,211 7,215 20,483 11,077 375 8,685 159 26,331 (20,609) 1,195 176 65 450 26,250 30,000 B. Permitting - - - - - - - - - - - - - - - - - - C. Legal - - - - - - - - - - - - - - - - - - D. Real Estate - - - 79,854 258,986 6,272 (6,766) 56,296 (65,303) 1,157 1,123 1,443 3,195 3,598 4,779 127,028 227,500 130,000 E. Right of Way & Easement - - - 137,024 (142,609) 1,714 22,181 20,338 - - - - - 884 8,757 (57,480) 166,250 80,000 F. Materials - pipe - - - - - - - - - - - - - - - - - - G. Materials - other - - - 446 - 4,494 255 - 43,500 (43,500) - 69 - - 25 - - - H. Engineering & Design - - - 88,867 19,679 237,396 171,908 7,993 10,756 15,399 11,875 12,802 103,732 46,219 206,571 (95,796) 236,250 200,000 I. Construction - - - 52,234 20,654 4,097 9,244 9,451 16,392 43,722 - - 1,674 9,837 25,527 17,670 - - J. Environmental - - - 122,353 - 8,671 3,559 39 31 31 31 31 147 1,969 2,596 31 17,500 20,000 K Lab Services - - - - - - - - - - - - - - - 337 - - L. Misc Other Services - - - 577,617 112,245 850 (112,405) 217,874 41,719 6,659 207 72 14,011 2,186 567 - - -

M. Admin & General Overhead - - - 14,765 7,647 25,609 26,357 6,324 3,907 1,995 1,680 2,229 2,447 4,387 5,454 7,566 234,150 134,000 N. Contingency - - - - - - - - - - - - - - - - 389,100 148,500

Total - - - 1,364,372 283,818 309,585 125,409 318,690 59,687 25,622 41,247 (3,963) 126,400 69,256 254,340 (194) 1,297,000 742,500 COR - - - 40,931 8,515 9,288 3,762 9,561 1,791 769 1,237 (119) 3,792 2,078 7,630 (6) 38,910 22,275 Total CAP (No COR) - - - 1,323,440 275,304 300,297 121,646 309,129 57,896 24,853 40,010 (3,844) 122,608 67,178 246,710 (188) 1,258,090 720,225

Project Description GL- 02629 FDM - Line 100A - Williamston City Gate to Chelsea Interchange – 29.7 Miles of36" Pipe Installation2013 2014 2015 2016 Jan-17 Feb-17 Mar-17 Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 2018 Jan-June 2019

A. Survey - - - - - - - - - - - - - - - - 26,250 30,000 B. Permitting - - - - - - - - - - - - - - - - - - C. Legal - - - - - - - - - - - - - - - - - - D. Real Estate - - - - - - - - - - - - - - - - 227,500 130,000 E. Right of Way & Easement - - - - - - - - - - - - - - - - 166,250 80,000 F. Materials - pipe - - - - - - - - - - - - - - - - - - G. Materials - other - - - - - - 1,680 132 - 484 - - - 25 - - - - H. Engineering & Design - - - - - - 56,369 0 - - - - 30,447 85,145 - 315,893 236,250 200,000 I. Construction - - - - - - - - - - - - - - - - - - J. Environmental - - - - - - - - - - - - - - - - 17,500 20,000 K Lab Services - - - - - - - - - - - - - - - - - - L. Misc Other Services - - - - - - - - - - - - - - - - - -

M. Admin & General Overhead - - - - - - 10,423 114 - 180 - - 3,654 6,234 - 25,534 234,150 134,000 N. Contingency - - - - - - - - - - - - - - - - 389,100 148,500

Total - - - - - - 68,472 246 - 664 - - 34,101 91,405 - 341,427 1,297,000 742,500 COR - - - - - - 2,054 7 - 20 - - 1,023 2,742 - 10,243 38,910 22,275 Total CAP (No COR) - - - - - - 66,418 239 - 644 - - 33,078 88,663 - 331,184 1,258,090 720,225



Project Description St. Clair Compressor Station Upgrade2013 2014 2015 2016 Jan-17 Feb-17 Mar-17 Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 2018 Jan-June 2019

A. Survey 82,907 73,199 48,447 - - - - - 7,174 - - - - - - - - B. Permitting - - - - - - - - - - - - - - - - - - C. Legal - - - - - - - - - - - - - - - - - - D. Real Estate - - - - - - - - - - - - - - - - - - E. Right of Way & Easement - - - - - - - - - - - - - - - - - - F. Materials - pipe - - 1,703,244 1,748,164 - - - - - - - - - - - - - - G. Materials - other - 6,274,001 16,873,314 9,875,889 (24,445) 1,968,730 (7,362) (144,349) (18,884) 96,846 1,800,791 146,052 280,033 (456,952) 15,836 975,334 981,000 - H. Engineering & Design 298,900 4,161,020 10,959,120 211,655 639 18,147 34,939 (512,730) 109,934 104,905 100,365 87,114 39,669 50,169 45,961 51,478 - - I. Construction - - 23,665,825 47,595,711 3,558,709 4,136,907 2,828,347 2,618,183 1,793,496 1,791,208 1,404,996 1,716,997 196,046 1,603,317 153,695 8,233,914 435,000 - J. Environmental - 23,909 37,098 9,111 - - - - 203 2,621 - - - - - - - - K Lab Services - 23,497 43,388 282,991 21,388 20,321 15,725 22,648 35,218 7,300 11,140 - 30,669 1,170 - - - - L. Misc Other Services - 1,744,120 1,383,061 124,552 6,794 3,521 17,863 4,953 15,238 49,490 33,536 745 30,130 116,577 25,093 133,688 - -

M. Admin & General Overhead 37,742 1,599,594 5,901,669 12,804,254 1,326,263 1,285,218 1,069,962 455,095 705,897 834,524 737,130 752,253 595,750 799,441 571,407 372,091 950,000 - N. Contingency - - - - - - - - - - - - - - - - - -

Total 336,642 13,909,048 60,639,918 72,700,774 4,889,348 7,432,844 3,959,474 2,443,799 2,641,101 2,894,068 4,087,959 2,703,160 1,172,296 2,113,722 811,992 9,766,504 2,366,000 - COR - - - - - - - - - - - - - - - - - - Total CAP (No COR) 336,642 13,909,048 60,639,918 72,700,774 4,889,348 7,432,844 3,959,474 2,443,799 2,641,101 2,894,068 4,087,959 2,703,160 1,172,296 2,113,722 811,992 9,766,504 2,366,000 -

Project Description Freedom Compressor Station Upgrade2013 2014 2015 2016 Jan-17 Feb-17 Mar-17 Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 2018 Jan-June 2019

A. Survey - 15,000 - - - - - - - - - - - - - - - - B. Permitting - - 15,000 - - - - - - - - - - - - - - - C. Legal - - - - - - - - - - - - - - - - - - D. Real Estate - - - - - - - - - - - - - - - - - - E. Right of Way & Easement - - - - - - - - - - - - - - - - - - F. Materials - pipe - - - 625,631 - - - - - - - - - - - - - - G. Materials - other - - 411,321 1,906,581 6,683,970 - 11,405 - - 86,773 - 1,241,635 405,975 4,960 2,558,841 1,014,699 15,251,471 3,751,451H. Engineering & Design - 76,297 599,599 2,620,546 425,595 601,177 719,484 450,639 619,620 808,511 468,217 479,960 480,155 399,367 496,818 515,261 4,000,000 900,000I. Construction - - 188,711 6,658,453 154,231 725,872 104,028 140,157 22,840 37,577 455,172 218,572 644,480 455,948 848,106 835,760 17,325,762 17,594,018J. Environmental - - 8,055 39,243 270 - 10,275 - 11,396 5,511 - - 9,996 - 4,549 - - - K Lab Services - - - - - - - 485 - - - - - - - - - - L. Misc Other Services - - 788 31,736 1,590 1,233 1,892 - 875 1,750 875 - 1,750 875 1,707 875 3,129,410 3,370,348

M. Admin & General Overhead 24,960 98,973 177,028 4,934,019 1,077,590 455,614 468,619 329,759 342,415 290,471 391,342 506,294 465,959 481,483 907,803 599,227 6,648,801 5,581,905N. Contingency - - - - - - - - - - - - - - - - 6,864,556 3,124,278

Total 24,960 190,270 1,400,502 16,816,208 8,343,246 1,783,896 1,315,703 921,040 997,146 1,230,593 1,315,606 2,446,461 2,008,315 1,342,633 4,817,824 2,965,822 53,220,000 34,322,000 COR - - - - - - - - - - - - - - - - - - Total CAP (No COR) 24,960 190,270 1,400,502 16,816,208 8,343,246 1,783,896 1,315,703 921,040 997,146 1,230,593 1,315,606 2,446,461 2,008,315 1,342,633 4,817,824 2,965,822 53,220,000 34,322,000



STATE OF MICHIGAN

RICK SNYDERGOVERNOR

DEPARTMENT OF LICENSING AND REGULATORY AFFAIRSPUBLIC SERVICE COMMISSION

SHELLY EDGERTONDIRECTOR

NORM SAARI SALLY A. TALBERG RACHAEL EUBANKSCOMMISSIONER CHAIRMAN COMMISSIONER

LARA is an equal opportunity employer/program.Auxiliary aids, services and other reasonable accommodations are available upon request to individuals with disabilities.

7109 W. SAGINAW HIGHWAY P.O. BOX 30221 LANSING, MICHIGAN 48909 www.michigan.gov/mpsc 517-284-8100

February 24, 2017

Delivery Method: Electronic Mail

Ms. Mary P. PalkovichVice President of Energy DeliveryConsumers Energy1945 West Parnall RoadP26-336BJackson, MI 49201-8658

Subject: Non-Compliance 368525

Dear Ms. Palkovich:

On May 3, 2016, and June 2, 2016, Michigan Public Service Commission Staff Engineer Mrs. Heather David inspected Midland Cogeneration Venture (MCV), previously operated by Consumers Energy (Consumers). As a result of the inspection, it appears that Consumers has committed a probable violation of the following:

49 CFR 192.195 entitled “Protection against accidental overpressuring.”49 CFR 192.481 entitled “Atmospheric corrosion control: Monitoring.”49 CFR 192.739 entitled “Pressure limiting and regulating stations: Inspection and testing.”

49 CFR 192.195(a)

49 CFR 192.195(a) states in part that:

Each pipeline that is connected to a gas source so that the maximum allowable operating pressure could be exceeded as the result of pressure control failure or of some other type of failure, must have pressure relieving or pressure limiting devices that meet the requirements of §192.199 and §192.201.

During the inspection, it was determined that there was not overpressure protection to protect Line 8100 from the higher maximum allowable operating pressure (MAOP) of Line 100. Line 8100 has an MAOP of 788 pounds per square inch gauge (psig) compared to Line 100’s MAOP of 800 psig.



Ms. Mary P. PalkovichNon-Compliance 368525Page 2 of 3February 24, 2017

Failure to have pressure relieving or pressure limiting devices that meet the requirements of §192.199 and §192.201 for each pipeline that is connected to a gas source so that the maximum allowable operating pressure could be exceeded as the result of pressure control failure or of some other type of failure is a violation of 49 CFR 192.195(a).

49 CFR 192.481(a)

49 CFR 192.481(a) states in part that “Each operator must inspect each [onshore] pipeline or portion of pipeline that is exposed to the atmosphere for evidence of atmospheric corrosion … at least once every 3 calendar years, but with intervals not exceeding 39 months.”

Atmospheric corrosion inspections took place on August 29, 2011, and September 2, 2014. However, the September 2, 2014 documentation did not demonstrate that the four-inch meter run at MCV Interchange M-12 was inspected for atmospheric corrosion.

Failure to inspect each onshore pipeline or portion of pipeline that is exposed to the atmosphere for evidence of atmospheric corrosion at least once every three calendar years, but with intervals not exceeding 39 months, is a violation of 49 CFR 192.481(a).

49 CFR 192.739(a)(3)

49 CFR 192.739(a) states in part that:

Each pressure limiting station, relief device (except rupture discs), and pressure regulating station and its equipment must be subjected at intervals not exceeding 15 months, but at least once each calendar year, to inspections and tests to determine that it is–* * *(3) Except as provided in paragraph (b) of this section, set to control or relieve at the correct pressure consistent with the pressure limits of §192.201(a)...

During the inspection, it was determined that the Shaffer Actuator Valve 8020 (overpressure protection for Line 8020) located at the TransCanada Interconnect had not been confirmed to control at the correct pressure during the September 10, 2013 and March 27, 2014 inspections. Additionally, the Shaffer Actuator Valves 12 and 16 (overpressure protection for MCV’s facilities) located at the MCV Interchange M-12 had not been confirmed to control at the correct pressure during the inspections from 2012 through 2015.

Failure to determine that each pressure limiting station, relief device, and pressure regulating station and its equipment are set to control or relieve at the correct pressure consistent with the pressure limits of 49 CFR 192.201(a) at intervals not exceeding 15 months, but at least once each calendar year, is a violation of 49 CFR 192.739(a)(3).



Ms. Mary P. PalkovichNon-Compliance 368525Page 3 of 3February 24, 2017

Summary

The Commission’s jurisdiction in this matter is pursuant to Public Act 165 of 1969, MCL 483.151 et seq. Failure to correct the issues identified in this notice could lead to further enforcement action by the Commission, up to and including a fine of not more than $10,000.00 for each violation, for each day that the violation persists.

If you do not wish to contest the findings of probable non-compliance, please send a response within 90 days from the date of this letter indicating how Consumers will correct the itemsidentified above, a completion date for the corrections, and how Consumers will prevent the reoccurrence of similar non-compliance issues.

If you require clarification regarding this notice or wish to contest the findings, please contact Mrs. David at 517-256-0342 or [email protected].

Sincerely,

David J. Chislea, ManagerGas Operations SectionOperations and Wholesale Markets Division

cc: Brian Ballinger, MPSCGas Safety Engineers, MPSCJulie Hegedus, Consumers [email protected] Ward, Consumers Energy

Digitally signed by David Chislea (tlm) DN: cn=David Chislea (tlm), o=Michigan Public Service Commission, ou=Manager, Gas Operations, [email protected], c=US Date: 2017.02.22 11:12:36 -05'00'



A CMS ENERGY COMPANY May 25, 2017

Mr. David Chislea Michigan Public Service Commission 7109 W. Saginaw Highway PO Box 30221 Lansing, MI 48909-7721 RE: Non-Compliance 2017-368525 Mr. Chislea: Consumers Energy is in receipt of the MPSC Gas Safety Staff’s February 24, 2017 letter of probable violation of 192.195, 192.481, and 192.739 entitled “Protection against accidental overpressuring”, “Atmospheric corrosion control: Monitoring” and “Pressure limiting and regulating stations: Inspection and testing” (Non-Compliance 368525). With respect to Staff's indicated violation of 192.195:

“Each pipeline that is connected to a gas source so that the maximum allowable operating pressure could be exceeded as the result of pressure control failure or of some other type of failure, must have pressure relieving or pressure limiting devices that meet the requirements of §192.199 and §192.201”

Consumers Energy requests that Staff rescind the violation for 192.195:

A. During a conference call on February 9th with the MPSC and Consumers Energy employees, overpressure protection was discussed. Per email dated, 1/24/2017 from Heather David, “I do not believe we have any further follow-up requests”. No further action will be taken by Consumers Energy.

With respect to Staff's indicated violation of 192.481:

“Each operator must inspect each [onshore] pipeline or portion of pipeline that is exposed to the atmosphere for evidence of atmospheric corrosion … at least once every 3 calendar years, but with intervals not exceeding 39 months.”

Consumers Energy requests that Staff consider the following:

A. Gas Operations Manual 11.6 Aboveground Corrosion Inspection – T&S Facilities outlines the requirements for inspecting the external pipe and coating on above grade pipe and at ground line transitions. Therefore, Consumers Energy has a procedure in place to address the requirements contained within 192.481.

B. Maps have been updated to include atmospheric corrosion inspection points.



C. The above location is no longer operated by Consumers Energy, as of October 2015. With respect to Staff's indicated violation of 192.739:

“Each pressure limiting station, relief device (except rupture discs), and pressure regulating station and its equipment must be subjected at intervals not exceeding 15 months, but at least once each calendar year, to inspections and tests to determine that it is– * * * (3) Except as provided in paragraph (b) of this section, set to control or relieve at the correct pressure consistent with the pressure limits of §192.201(a)..”

Consumers Energy requests that Staff consider the following:

A. Pressure limiting and emergency shut down devices (aka PLD/ESD) have been removed from valve inspection maintenance plans.

B. PLD/ESD maintenance plans were reviewed and final updates completed in 1st quarter 2017. C. GOM 12.8 and Work Method 140 have been updated to capture the “as found, as left, and set

point” on October 3, 2016. D. Form 1002 – Pressure Limiting Device (PLD)/Emergency Shutdown Device (ESD) Inspection

Report was updated October 2016 to reflect the appropriate documentation requirements for applicable equipment using Work Method 140. – See attachment A (Form 1002).

E. Shaffer Actuator Valves 12, 16, and 8020 are no longer operated by Consumers Energy, as of October 2015.

Consumers Energy considers the actions outlined in above to satisfactorily address Non-Compliance 368525. Consumers Energy will submit a final resolution letter to Non-Compliance 368525. Please contact me if you have any questions or comments. Thank you, Beth L. Fields Director of Regulatory & Compliance Consumers Energy P23-420 1945 W. Parnall Rd Jackson, MI 49201 517-788-2269 [email protected] CC: MPPalkovich, P25-412

CCCrews, Livonia MRomein, Liv100-46 RWBeach, OEP 11-241 HDavid, MPSC ZKOliver, Lansing



MSBeach, JAC107a MDPahl, JAC151-4 SJZielinski, GRO100-25 CANaessens, SAG258 CKuchar, SGO134 BFritz, GRA208 SVWatson, Livonia 300-3 ALWard, Howell 102-29 CQKing, Livonia 300-6 KMcNeil, Livonia 300-11 ABartkus, Parnall P23-429 MSkillmanWalker, Royal Oak 2-234 CMBuhler, Owosso 129-1 PO Box: CE Regulatory Services



Station/Site: Order Number:

PLD/ESD OPERATOR INSPECTION

PLD/ESD Device ID Set Pressure (psig) “As Found” (psig) “As Left” (psig) Operation (check one)

1. 2. 3. 4. 5. 6.

PLD/ESD VALVE INSPECTION

PLD/ESD Device ID Valve Position* (check one)

Valve Condition** (check one) Comments

1.

2.

3.

4.

5.

6.



A CMS ENERGY COMPANY August 15, 2017

Mr. David Chislea Michigan Public Service Commission 7109 W. Saginaw Highway PO Box 30221 Lansing, MI 48909-7721 RE: Non-Compliance 2017-368525 Mr. Chislea: Consumers Energy is in receipt of the MPSC Gas Safety Staff’s February 24, 2017 letter of probable violation of 192.195, 192.481, and 192.739 entitled “Protection against accidental over pressuring”, “Atmospheric corrosion control: Monitoring” and “Pressure limiting and regulating stations: Inspection and testing” (Non-Compliance 368525). With respect to Staff's indicated violation of 192.195:

“Each pipeline that is connected to a gas source so that the maximum allowable operating pressure could be exceeded as the result of pressure control failure or of some other type of failure, must have pressure relieving or pressure limiting devices that meet the requirements of §192.199 and §192.201”

Consumers Energy requests that Staff consider the following for 192.195:

A. Line 8100 is no longer operated by Consumers Energy, as of October 2015. B. As the owner of line 8100, MCV is responsible for the installation of over pressure protection

(OPP) on their facility.

Consumers Energy will submit a final resolution letter to Non- Compliance 368525 by December 31, 2017. Please contact me if you have any questions or comments. Thank you, Beth L. Fields Director of Gas Compliance Consumers Energy P23-420



1945 W. Parnall Rd Jackson, MI 49201 517-788-2269 [email protected] CC: MPPalkovich, P25-412

SHBowers, P23-100 CCCrews, Livonia MRomein, Liv100-46 RWBeach, OEP 11-241 HDavid, MPSC ZKOliver, Lansing MSBeach, JAC107a MDPahl, JAC151-4 SJZielinski, GRO100-25 CANaessens, SAG258 CKuchar, SGO134 BFritz, GRA208 SVWatson, Livonia 300-3 ALWard, Howell 102-29 CQKing, Livonia 300-6 KMcNeil, Livonia 300-11 ABartkus, Parnall P23-429 MSkillmanWalker, Royal Oak 2-234 CMBuhler, Owosso 129-1 PO Box: CE Regulatory Services [email protected]



A CMS ENERGY COMPANY August 15, 2017

Mr. David Chislea Michigan Public Service Commission 7109 W. Saginaw Highway PO Box 30221 Lansing, MI 48909-7721 RE: Over pressure protection engineering analysis Mr. Chislea: Pursuant to Consumers Energy’s discussion with the MPSC Staff in response to non-compliance # 368525, Consumers Energy will conduct an engineering analysis to determine potential locations on its system where overpressure protection may be required pursuant to the Michigan Gas Safety Code or additional automatic pressure sensing devices are recommended for improved safety. This analysis will be completed and submitted prior to December 31st, 2017. Please contact me if you have any questions or comments. Thank you, Beth L. Fields Director of Gas Compliance Consumers Energy P23-420 1945 W. Parnall Rd Jackson, MI 49201 517-788-2269 [email protected] CC: MPPalkovich, P25-412

SHBowers, P23-100 CCCrews, Livonia JSPionk SAG-228 MRomein, Liv100-46 RWBeach, OEP 11-241 HDavid, MPSC



ZKOliver, Lansing MSBeach, JAC107a MDPahl, JAC151-4 SJZielinski, GRO100-25 CANaessens, SAG258 CKuchar, SGO134 BFritz, GRA208 SVWatson, Livonia 300-3 ALWard, Howell 102-29 CQKing, Livonia 300-6 KMcNeil, Livonia 300-11 ABartkus, Parnall P23-429 MSkillmanWalker, Royal Oak 2-234 CMBuhler, Owosso 129-1 PO Box: CE Regulatory Services [email protected]



A CMS ENERGY COMPANY December 21, 2017

Mr. David Chislea Michigan Public Service Commission 7109 W. Saginaw Highway PO Box 30221 Lansing, MI 48909-7721 RE: Over pressure protection engineering analysis for Non-Compliance #368525 Mr. Chislea: As a follow up to Consumers Energy’s response letter dated 8-14-2017 to non-compliance # 368525. Consumers Energy performed an engineering analysis to determine potential locations on its system where overpressure protection may be required pursuant to the Michigan Gas Safety Code or where additional automatic pressure sensing devices are recommended for improved safety. This analysis is attached. Please contact me if you have any questions or comments. Thank you, Beth L. Fields, PE Director of Gas Compliance Consumers Energy P23-420 1945 W. Parnall Rd Jackson, MI 49201 517-788-2269 [email protected]



CC: MPPalkovich, P25-412 SHBowers, P23-100 CCCrews, Livonia JSPionk SAG-228 MRomein, Liv100-46 RWBeach, OEP 11-241 HDavid, MPSC ZKOliver, Lansing SJorgenson, Lansing MSBeach, JAC107a MDPahl, JAC151-4 SJZielinski, GRO100-25 CANaessens, SAG258 CKuchar, SGO134 BFritz, GRA208 SVWatson, Livonia 300-3 ALWard, Howell 102-29 CQKing, Livonia 300-6 KMcNeil, Livonia 300-11 ABartkus, Parnall P23-429 MSkillmanWalker, Royal Oak 2-234 CMBuhler, Owosso 129-1 PO Box: CE Regulatory Services [email protected]

Attachment(s): 12-18-2017 - Non Compliance 2017-368525 CE Engineering Analysis.pdf



Consumers Energy's MAOP/PLD Engineering Analysis

An engineering analysis review was conducted on the gas transmission system in regards to Maximum Allowable Operating Pressure, (MAOP). Each location where pipelines of differing MAOP connect was evaluated to determine if pressure relieving or pressure limiting equipment was present.

The review took into account plans to replace portions of Line #2800 and Line #100A with the Saginaw Trail Pipeline and the Mid-Michigan Pipeline projects respectively.

A listing of locations where pressure relieving or pressure limiting equipment is not present is included below along with a proposed schedule to install that equipment.

Based upon engineering analysis and the operation of the gas transmission system, the locations listed below will not see pressures that will cause a safety concern due to pressure gradients, city gate stations and other transmission pipelines between the compressor stations and the third party feed locations, and the location of the MAOP differences on the transmission system.

MAOP/PLD Installation Schedule 5 Year Plan

Year of Installation Location

20182018201820182018201820182018

Line #100B - South of Valves 122-26, 501X20S and 8GSVS at Ovid Valve SiteLine #250 - East of Valve 253-16 at Zilwaukee JunctionLine #300 - South of Valve 314-12 at Zilwaukee JunctionLine #700 - At Thomas Township Valve SiteLine #1100 - At Valve 1164 at Laingsburg InterchangeLine #1300 - West of Valve 1318 on Line #1800 at Plainwell Valve SiteLine #2400 - At Valve 306 at Muskegon River Compressor StationLine #2400A - North of Valve 2420C at Gillow Road Valve Site

201920192019201920192019

Line #500 - West of Valve 508-16 at Grand Blanc InterchangeLine #600 - At Valve 601-24 at Clarkston Valve SiteLine #1020 - At Valve 1022 at South Lyons-Whitmore Lake City GateLine #2700 - At Valve 2737 at Dixie-Waterford City GateLine #4060 - West of Valve 4068 at Vector M&R Station, Old US-23 HighwayLine #4070 - East of Valve 1713 at Vector M&R Station, 29 Mile Road

2020202020202020202020202020

Line #400 - At Valve 405T16 at Clarkson Valve SiteLine #2070 - At Valve 2070 at Dutton Road Interchange Line #2700 - At Valve 2726 at Dutton Road Interchange Line #2700 - At Valve 2725 at Squirrel Road Valve Site Line #2700 - At Valve 2743 at Clarkston Valve SiteLine #2800 - At Valve 2826T16 at Clarkston Valve Site Line #2800 - North of Valve 2822 at Clawson Control Station



MAOP/PLD Installation Schedule (Contd) 5 Year Plan

Year of Installation Location

202120212021

Line #1200A - East of Valve 1252A at Hanover-Horton City GateLine #1800 - South of Valves 1817 and 1818 at Plainwell Valve SiteLine #2030(#100A) - South of Valves 1263A and 1265A at Chelsea Valve Site

20222022

Line #100A - South of Valves 122-20 and 501X16S at Ovid Valve Site Line #100B - North of new Valve 124-36 at Laingsburg Valve Site

12/18/2017




.

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 01/23/2018 NO. CLC-11 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 1/31/18 RESPONDENT: Mary P. Palkovich Question: 1. With reference to Company Exhibit A-63 (MPP-15), please provide the expenditure amounts by

month for 2017 through June 2019. Also, please indicate for each project if it is included in the TED-I Transmission or Transmission Distribution program (per Lines 2 and 4 of Exhibit A-59 (MPP-12)).

Answer: For purposes of responding to this interrogatory the Company assumes the question is referring to Exhibit A-63 (MPP-16). Please see the attachment entitled U-18424 MPSC Staff Audit 154 Attachment. Distribution projects on the attachment are highlighted in yellow. All other projects are Transmission.

Case No.: U-18424 Exhibit No.: S-11.33 Witness: C. Creisher

Page: 1 of 1

U-18424 MPSC Staff Audit 154 AttachmentMICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-18424Consumers Energy Company Exhibit No.: A-63 (MPP-16)Actual & Projected Gas Capital Expenditures for Year 2016 through June 30, 2019 Page: 1 of 15Capacity/Deliverability Program Witness: MPPalkovich($000) Date: October 2017

(b) (c) (d) (e) 2017LineNo. TED-I Non Major Pipeline Project Detail 2016 2017 2018 6 ME 6/30/19

Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 KZO-1200B Hackman to Lutes Pipe Inst 23 3 Materials 20 4 Contract Labor 0 5 CE Labor - 6 Engineering - 7 Allocations 1 8 Other 1 9 Contingency -

1011 STC-1700 Macomb Jct PLD Inst 329 12 Materials 122 13 Contract Labor 43 14 CE Labor 63 15 Engineering - 16 Allocations - 17 Other 101 18 Contingency - 1920 FDM-100A Freedom Pipeline Repl 644 21 Materials 98 22 Contract Labor 503 23 CE Labor 22 24 Engineering 3 25 Allocations 9 26 Other 10 27 Contingency - 2829 SAG-300 N Bradley VS PLD Inst 762 30 Materials 149 31 Contract Labor 538 32 CE Labor 26 33 Engineering 4 34 Allocations 39 35 Other 5 36 Contingency - 3738 FDM-1100 Laingsburg Interchange PLD 0 39 Materials 0 40 Contract Labor - 41 CE Labor 0 42 Engineering - 43 Allocations - 44 Other 0 45 Contingency - 46

(a)


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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 FDM-10-1 Line Modifications 2,649 3 Materials 454 4 Contract Labor 1,688 5 CE Labor 319 6 Engineering 37 7 Allocations 105 8 Other 46 9 Contingency -

1011 JXN-Temp Odorizer Trailers, Meters 188 12 Materials 117 13 Contract Labor - 14 CE Labor 15 15 Engineering - 16 Allocations 56 17 Other - 18 Contingency - 1920 SAG-Bridgeport CG Rbld 349 21 Materials 217 22 Contract Labor 46 23 CE Labor 50 24 Engineering 2 25 Allocations 16 26 Other 17 27 Contingency - 2829 SAG-Clio CG Rbld 18 30 Materials - 31 Contract Labor 16 32 CE Labor 1 33 Engineering - 34 Allocations 0 35 Other 1 36 Contingency - 3738 STC-NovWxm CG Vlv 1616,1617 RCV Inst 108 39 Materials 60 40 Contract Labor - 41 CE Labor 26 42 Engineering - 43 Allocations 15 44 Other 7 45 Contingency - 46

(a)


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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total123 STC - Line 2070 - Wattles Road Valve Site - Valve 2074 RCV Installation 1,208 4 Materials 672 5 Contract Labor - 6 CE Labor 315 7 Engineering - 8 Allocations 170 9 Other 50

10 Contingency - 1112 City Gate Engineering, Materials, Prefab - Sag Trail 392 13 Materials 88 14 Contract Labor 246 15 CE Labor 43 16 Engineering - 17 Allocations 11 18 Other 5 19 Contingency - 2021 City Gate Engineering, Materials, Prefab - Mid Michigan 365 22 Materials 88 23 Contract Labor 226 24 CE Labor 35 25 Engineering - 26 Allocations 11 27 Other 5 28 Contingency - 2930 Engineering & Real Estate - S. Oakland/Macomb Net - Dist 2,040 31 Materials - 32 Contract Labor - 33 CE Labor - 34 Engineering 600 35 Allocations 40 36 Other 1,400 37 Contingency -

(a)


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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 Engineering & Real Estate - S Oakland/Macomb Network 591 3 Materials - 4 Contract Labor - 5 CE Labor - 6 Engineering 400 7 Allocations 136 8 Other 55 9 Contingency -

10

11 MAR Line 2400A - Gillow Road Valve Site - 12" Monitor/Worker PLD Installations 581 1,124 84 22 22 20 18 190 48 104 35 6 31 1 581 12 Materials 40 326 6 2 2 1 1 13 3 7 2 0 2 0 4013 Contract Labor 3 384 0 0 0 0 0 1 0 1 0 0 0 0 314 CE Labor 8 12 1 0 0 0 0 3 1 1 0 0 0 0 815 Engineering 65 40 9 2 3 2 2 21 5 12 4 1 3 0 6516 Allocations 16 39 2 1 1 1 0 5 1 3 1 0 1 0 1617 Other 449 150 65 17 17 15 14 147 37 81 27 4 24 0 44918 Contingency - 173 0 0 0 0 0 0 0 0 0 0 0 0 019

20SAG Line 500 - Grand Blanc Interchange - 26" Monitor/Worker Installations West of Valve 508-16. 410 10 351 59 15 16 14 13 134 34 74 25 4 22 0 410

21 Materials 317 - 154 46 12 12 11 10 104 26 57 19 3 17 0 31722 Contract Labor 5 - 119 1 0 0 0 0 2 0 1 0 0 0 0 523 CE Labor 14 - 4 2 1 1 0 0 5 1 3 1 0 1 0 1424 Engineering 53 10 12 8 2 2 2 2 17 4 10 3 1 3 0 5325 Allocations 14 - 12 2 1 1 0 0 5 1 3 1 0 1 0 1426 Other 7 - 50 1 0 0 0 0 2 1 1 0 0 0 0 727 Contingency - - - 0 0 0 0 0 0 0 0 0 0 0 0 028

29SAG - Line 100B - Ovid Valve Site - 26" Monitor/Worker Installations South of Valves 122-26, 501X20S and 8GSV5. 400 1,174 58 15 15 14 12 131 33 72 24 4 21 0 400

30 Materials 309 324 45 12 12 11 9 101 26 55 19 3 16 0 30931 Contract Labor 5 438 1 0 0 0 0 2 0 1 0 0 0 0 532 CE Labor 12 12 2 0 0 0 0 4 1 2 1 0 1 0 1233 Engineering 53 40 8 2 2 2 2 17 4 10 3 1 3 0 5334 Allocations 14 39 2 1 1 0 0 5 1 3 1 0 1 0 1435 Other 7 150 1 0 0 0 0 2 1 1 0 0 0 0 736 Contingency - 171 0 0 0 0 0 0 0 0 0 0 0 0 037

(a)


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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total1

2FDM - Line 1100 - Laingsburg Interchange - 24" Monitor/Worker Installations at Valve 1164. 1,078

3 Materials 367 4 Contract Labor 350 5 CE Labor 11 6 Engineering 36 7 Allocations 36 8 Other 120 9 Contingency 158

10

11KAL - Line 1300- Plainwell Valve Site - 20" Monitor/Worker PLD Installations at Valve 1318 286 1,991 41 11 11 10 9 94 24 51 17 3 15 0 286

12 Materials 218 685 32 8 8 7 7 71 18 39 13 2 11 0 21813 Contract Labor 8 652 1 0 0 0 0 3 1 1 0 0 0 0 814 CE Labor 11 26 2 0 0 0 0 4 1 2 1 0 1 0 1115 Engineering 36 84 5 1 1 1 1 12 3 6 2 0 2 0 3616 Allocations 9 83 1 0 0 0 0 3 1 2 1 0 0 0 917 Other 4 200 1 0 0 0 0 1 0 1 0 0 0 0 418 Contingency - 262 0 0 0 0 0 0 0 0 0 0 0 0 019

20MAR Line 2400 - Muskegon River Compressor Station - 16" Monitor/Worker Installations at Valve 306. 1,269

21 Materials 442 22 Contract Labor 419 23 CE Labor 17 24 Engineering 54 25 Allocations 54 26 Other 100 27 Contingency 185 28

29STC Line 400 - Clarkston Junction - 16" Monitor/Worker Installations at Valve 405T16. 1,269

30 Materials 442 31 Contract Labor 419 32 CE Labor 17 33 Engineering 54 34 Allocations 54 35 Other 100 36 Contingency 185 37

38SAG Line 8100 - Summerton Road Valve Site - 20" Monitor/Worker Installations East of Valves 8110 and 8112. 1,308


(a)


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2FDM Line 4060 - Vector M&R Station - 16" Monitor/Worker Installations West of Valve 4068. 1,301


10

11FDM Line 4070 - Vector M&R Station - 16" Monitor/Worker Installations East of Valve 1713. 20 395

12 Materials - 141 13 Contract Labor - 136 14 CE Labor - 5 15 Engineering 20 17 16 Allocations - 17 17 Other - 20 18 Contingency - 59 19

20STC Line 600 - Clarkston Interchange - 24" Monitor/Worker Installations East of Valve 601-24. 20 446

21 Materials - 160 22 Contract Labor - 155 23 CE Labor - 6 24 Engineering 20 20 25 Allocations - 19 26 Other - 20 27 Contingency - 67 28

29STC Line 2700 - Clarkston Interchange - 24" Monitor/Worker Installations at Valve 2743. 6

30 Materials - 31 Contract Labor - 32 CE Labor - 33 Engineering 6 34 Allocations - 35 Other - 36 Contingency - 37

38STC Line 2700 - Dixie-Waterford City Gate - 24" Monitor/Worker Installations at Valve 2737. 20 446

39 Materials - 160 40 Contract Labor - 155 41 CE Labor - 6 42 Engineering 20 20 43 Allocations - 19 44 Other - 20 45 Contingency - 67

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2SAG - Line 250 - Zilwaukee City Gate - 16" Monitor/Worker PLD Installations at Valve 253-16. 982


1011 STC - Line 2070 - Coolidge City Gate - Valve 2076N Class 4 RCV Installation 144 12 Materials 61 13 Contract Labor - 14 CE Labor 33 15 Engineering - 16 Allocations 10 17 Other 40 18 Contingency1920 STC - Line 1600 - Greenfield City Gate - Valve "A" Class 4 RCV Installation 70 21 Materials 30 22 Contract Labor - 23 CE Labor 10 24 Engineering - 25 Allocations 5 26 Other 25 27 Contingency - 2829 STC - Line 1600 - Evergreen Valve Site - Valve "A" Class 4 RCV Installation 342 30 Materials 143 31 Contract Labor - 32 CE Labor 76 33 Engineering - 34 Allocations 24 35 Other 100 36 Contingency - 3738 STC - Line 2010 - Pontiac City Gate, Adams Road - "A" Valve RCV Installation 98 39 Materials 40 40 Contract Labor - 41 CE Labor 20 42 Engineering - 43 Allocations 10 44 Other 28 45 Contingency -

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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 STC - Line 2010 - Chrysler Tech Center - "A" Valve RCV Installation 172 3 Materials 70 4 Contract Labor - 5 CE Labor 35 6 Engineering - 7 Allocations 18 8 Other 49 9 Contingency -

10

11STC - Line 2010 - Pontiac City Gate, Walton Road - Valve 2014 & 2015 RCV Installations 194

12 Materials 79 13 Contract Labor - 14 CE Labor 40 15 Engineering - 16 Allocations 20 17 Other 55 18 Contingency - 1920 RCV Projects - 5 Per Year 160 21 Materials 31 22 Contract Labor 26 23 CE Labor 18 24 Engineering - 25 Allocations 15 26 Other 20 27 Contingency 51 2829 SAG - Line 700 - Saginaw Dutch Road City Gate - New Odorizer 1,119 30 Materials 212 31 Contract Labor 653 32 CE Labor 42 33 Engineering 42 34 Allocations 148 35 Other 21 36 Contingency - 3738 FLN - Line 2800 - Carpenter Road Valve Site - Odorizer Installation 346 39 Materials 67 40 Contract Labor 206 41 CE Labor 13 42 Engineering 13 43 Allocations 47 44 Other - 45 Contingency - 46

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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 SAG - Line 700 - Saginaw Dutch Road City Gate - City Gate Rebuild 3,759 3 Materials 712 4 Contract Labor 2,194 5 CE Labor 142 6 Engineering 142 7 Allocations 498 8 Other 71 9 Contingency -

1011 FLN - Line 2800 - Flint-Lapeer City Gate - New City Gate 1,079 12 Materials 224 13 Contract Labor 627 14 CE Labor 41 15 Engineering 41 16 Allocations 142 17 Other 5 18 Contingency - 1920 Plymouth City Gate Partial Rebuild & conversion to Reg Stn 993 21 Materials 229 22 Contract Labor 494 23 CE Labor 45 24 Engineering 45 25 Allocations 157 26 Other 22 27 Contingency - 28

291.9 mile West Wayne to Plymouth 12" HP Augment - S. Oakland/Macomb Net - Dist 10,570

30 Materials 2,114 31 Contract Labor 2,537 32 CE Labor 2,431 33 Engineering 1,057 34 Allocations 317 35 Other 2,114 36 Contingency - 3738 West Wayne City Gate Rebuild - S. Oakland/Macomb Net 4,169 39 Materials 791 40 Contract Labor 2,440 41 CE Labor 158 42 Engineering 158 43 Allocations 553 44 Other 69 45 Contingency -

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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 Prefab & material S. Oakland/Macomb Net 1,224 3 Materials 824 4 Contract Labor - 5 CE Labor 300 6 Engineering - 7 Allocations 100 8 Other - 9 Contingency -

10

11STC Line 2700 - Squirrel Road Valve Site - 26" Monitor/Worker Installations at Valve 2725. 6

12 Materials - 13 Contract Labor - 14 CE Labor - 15 Engineering 5 16 Allocations 1 17 Other - 18 Contingency - 19

20 STC Line 2700 - Dutton Road Interchange - 26" Monitor/Worker Installations at Valve 2726 6


29 STC Line 2070 - Dutton Road Interchange - 36" Monitor/Worker Installations at Valve 2070 6


38 STC Line 1020 - South Lyons-Whitmore Lake City Gate - 16" Monitor/Worker Installations at Valve 1022. 6

39 Materials - 40 Contract Labor - 41 CE Labor - 42 Engineering 5 43 Allocations 1 44 Other - 45 Contingency -

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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 Prefab & material NVL 3100 S. Oakland/Macomb Net - Dist 204 - 25 117 86 12 23 2 (61) - - - - 204 3 Materials - 0 0 0 0 0 0 0 0 0 0 0 0 04 Contract Labor 179 0 22 102 76 10 20 2 -53 0 0 0 0 1795 CE Labor 5 0 1 3 2 0 1 0 -1 0 0 0 0 56 Engineering - 0 0 0 0 0 0 0 0 0 0 0 0 07 Allocations 1 0 0 1 0 0 0 0 0 0 0 0 0 18 Other 19 0 2 11 8 1 2 0 -6 0 0 0 0 199 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 0

1011 SAG - Line 2800 - Birch Run-Montrose City Gate - City Gate Rebuild 2 - 1,907 12 Materials - 361 13 Contract Labor 0 1,113 14 CE Labor 0 72 15 Engineering 0 72 16 Allocations 0 253 17 Other 1 36 18 Contingency - - 19

20Distribution Augment - Lapeer Road City Gate to Flint Bristol Road City Gate – Sag Trail - Dist 5,908

21 Materials 1,182 22 Contract Labor 1,418 23 CE Labor 1,359 24 Engineering 591 25 Allocations 177 26 Other 1,182 27 Contingency - 28

29Distribution Augment - Shields City Gate to Saginaw Dutch Road City Gate - Sag Trail - Dist 6,974

30 Materials 1,395 31 Contract Labor 1,674 32 CE Labor 1,604 33 Engineering 697 34 Allocations 209 35 Other 1,395 36 Contingency - 3738 FDM - Line 1100 Laingsburg PLD 356 52 13 14 12 11 116 30 64 21 4 19 0 356 39 Materials 264 38 10 10 9 8 86 22 47 16 3 14 0 26440 Contract Labor 8 1 0 0 0 0 3 1 1 0 0 0 0 841 CE Labor 14 2 1 1 0 0 5 1 3 1 0 1 0 1442 Engineering 46 7 2 2 2 1 15 4 8 3 0 2 0 4643 Allocations 18 3 1 1 1 1 6 2 3 1 0 1 0 1844 Other 6 1 0 0 0 0 2 1 1 0 0 0 0 645 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 0

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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 Freedom Valve Site Upgrades - Mid Michigan 1,651 3 Materials - 4 Contract Labor 923 5 CE Labor 369 6 Engineering - 7 Allocations 185 8 Other 174 9 Contingency -

1011 City Gate Engineering, Materials, Prefab - Mid Michigan 284 12 Materials 155 13 Contract Labor 68 14 CE Labor - 15 Engineering 31 16 Allocations 29 17 Other - 18 Contingency - 1920 Ponitac Adams City Gate Rebuild S.Oakland/Macomb Net 1,944 21 Materials 374 22 Contract Labor 1,154 23 CE Labor 75 24 Engineering 75 25 Allocations 262 26 Other 5 27 Contingency - 282930 Utica City Gate Rebuild S.Oakland/Macomb Net 1,944 31 Materials 374 32 Contract Labor 1,154 33 CE Labor 75 34 Engineering 75 35 Allocations 262 36 Other 5 37 Contingency -

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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 New "Hayes" City Gate S. Oakland/Macomb Net 1,969 3 Materials 379 4 Contract Labor 1,169 5 CE Labor 76 6 Engineering 76 7 Allocations 265 8 Other 5 9 Contingency -

1011 New HP to HP Station S. Oakland/Macomb Net 2,062 12 Materials 1,088 13 Contract Labor - 14 CE Labor 472 15 Engineering - 16 Allocations 272 17 Other 230 18 Contingency - 1920 8.5 mile 20" 500 psig Augment Hayes to HP-HP S. Oakland/Macomb Net - Dist 29,876 21 Materials 5,975 22 Contract Labor 7,170 23 CE Labor 6,872 24 Engineering 2,988 25 Allocations 896 26 Other 5,975 27 Contingency - 2829 2.2 mile 12" steel Utica Lateral S. Oakland/Macomb Net - Dist 4,931 30 Materials 933 31 Contract Labor 2,879 32 CE Labor 187 33 Engineering 187 34 Allocations 653 35 Other 93 36 Contingency - 3738 1000 ft of 26" I-696 augment crossing S. Oakland/Macomb Net - Dist 558 39 Materials 112 40 Contract Labor 134 41 CE Labor 128 42 Engineering 56 43 Allocations 17 44 Other 112 45 Contingency -

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Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total12 1 mile 16" Augment on 14 Mile Rd - S. Oakland/Macomb Net - Dist 2,940 3 Materials 588 4 Contract Labor 705 5 CE Labor 676 6 Engineering 294 7 Allocations 88 8 Other 588 9 Contingency -

1011 Prefab & Material S. Oakland/Macomb Net 382 12 Materials 18013 Contract Labor14 CE Labor 12515 Engineering 7516 Allocations 217 Other18 Contingency 01920 Sag- TEDI Temp Reg Trailer - Transmission 397 58 15 15 14 12 130 33 71 24 4 21 0 397 21 Materials 101 15 4 4 3 3 33 8 18 6 1 5 0 10122 Contract Labor 184 27 7 7 6 6 60 15 33 11 2 10 0 18423 CE Labor 24 3 1 1 1 1 8 2 4 1 0 1 0 2424 Engineering 51 7 2 2 2 2 17 4 9 3 0 3 0 5125 Allocations 26 4 1 1 1 1 8 2 5 2 0 1 0 2626 Other 12 2 0 0 0 0 4 1 2 1 0 1 0 1227 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 02820 Sag- TEDI Temp Reg Trailer- Distribution 50 - 6 29 21 3 6 1 (15) - - - - 50 21 Materials 13 0 2 7 5 1 1 0 -4 0 0 0 0 1322 Contract Labor 23 0 3 13 10 1 3 0 -7 0 0 0 0 2323 CE Labor 3 0 0 2 1 0 0 0 -1 0 0 0 0 324 Engineering 6 0 1 4 3 0 1 0 -2 0 0 0 0 625 Allocations 3 0 0 2 1 0 0 0 -1 0 0 0 0 326 Other 1 0 0 1 1 0 0 0 0 0 0 0 0 127 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 028

29 FDM-100A Freedom Pipeline Repl 518 75 19 20 18 16 169 43 93 31 5 27 0 518 30 Materials 0 0 0 0 0 0 0 0 0 0 0 0 031 Contract Labor 506 73 19 20 17 16 165 42 91 30 5 27 0 50632 CE Labor 7 1 0 0 0 0 2 1 1 0 0 0 0 733 Engineering 2 0 0 0 0 0 1 0 0 0 0 0 0 234 Allocations 2 0 0 0 0 0 1 0 0 0 0 0 0 235 Other 1 0 0 0 0 0 0 0 0 0 0 0 0 136 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 03738 Project Total 4,963 3,152 47,636 58,0733940 Total Contigency (included in above) 0 0 1,650 243

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(b) (c) (d) (e) 2017LineNo.

TED-I Non Major Pipeline Project Detail 2016 2017 2018 6 ME 6/30/19Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total

1 Projects Inadvertently Excluded from Rate Case - 6,238 - - 23 SAG-Bridgeport CG Rbld Transm 1,621 1,621 4 Materials 401 58 15 16 14 12 131 33 72 24 4 21 0 4015 Contract Labor 846 123 32 33 29 26 277 71 152 51 8 44 1 8466 CE Labor 245 36 9 9 8 8 80 20 44 15 2 13 0 2457 Engineering - 0 0 0 0 0 0 0 0 0 0 0 0 08 Allocations - 0 0 0 0 0 0 0 0 0 0 0 0 09 Other 129 19 5 5 4 4 42 11 23 8 1 7 0 129

10 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 01112 SAG-Bridgeport CG Rbld 601 601 13 Materials 79 0 10 45 33 5 9 1 -24 0 0 0 0 7914 Contract Labor 450 0 56 257 190 26 51 5 -134 0 0 0 0 45015 CE Labor 43 0 5 25 18 2 5 0 -13 0 0 0 0 4316 Engineering - 0 0 0 0 0 0 0 0 0 0 0 0 017 Allocations - 0 0 0 0 0 0 0 0 0 0 0 0 018 Other 29 0 4 17 12 2 3 0 -9 0 0 0 0 2919 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 02021 SAG - Line 2800 - Birch Run-Montrose City Gate - City Gate Rebuild 606 606 22 Materials 231 33 9 9 8 7 76 19 41 14 2 12 0 23123 Contract Labor 86 13 3 3 3 3 28 7 16 5 1 5 0 8624 CE Labor 178 26 7 7 6 5 58 15 32 11 2 9 0 17825 Engineering - 0 0 0 0 0 0 0 0 0 0 0 0 026 Allocations - 0 0 0 0 0 0 0 0 0 0 0 0 027 Other 110 16 4 4 4 3 36 9 20 7 1 6 0 11028 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 02930 SAG-Clio CG Rbld Transm 2,233 2,233 31 Materials 437 63 16 17 15 13 143 36 78 26 4 23 0 43732 Contract Labor 1,669 242 63 65 57 51 546 139 300 100 16 88 2 166933 CE Labor 76 11 3 3 3 2 25 6 14 5 1 4 0 7634 Engineering - 0 0 0 0 0 0 0 0 0 0 0 0 035 Allocations - 0 0 0 0 0 0 0 0 0 0 0 0 036 Other 51 7 2 2 2 2 17 4 9 3 1 3 0 5137 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 03839 SAG-Clio CG Rbld Distrib 207 207 40 Materials 62 0 8 35 26 4 7 1 -19 0 0 0 0 6241 Contract Labor 79 0 10 45 33 5 9 1 -24 0 0 0 0 7942 CE Labor 47 0 6 27 20 3 5 1 -14 0 0 0 0 4743 Engineering - 0 0 0 0 0 0 0 0 0 0 0 0 044 Allocations - 0 0 0 0 0 0 0 0 0 0 0 0 045 Other 19 0 2 11 8 1 2 0 -6 0 0 0 0 1946 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 04748 DAPP:12236 BIRCH RUN CG AUGMENT eirp 389 389 49 Materials 49 0 6 28 21 3 6 1 -15 0 0 0 0 4950 Contract Labor 57 0 7 33 24 3 6 1 -17 0 0 0 0 5751 CE Labor 173 0 22 99 73 10 19 2 -52 0 0 0 0 17352 Engineering - 0 0 0 0 0 0 0 0 0 0 0 0 053 Allocations - 0 0 0 0 0 0 0 0 0 0 0 0 054 Other 110 0 14 63 46 6 12 1 -33 0 0 0 0 11055 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 05657 JAX Temporary Odorizers - 2017 581 581 58 Materials 338 49 13 13 12 10 111 28 61 20 3 18 0 33859 Contract Labor - 0 0 0 0 0 0 0 0 0 0 0 0 060 CE Labor 183 27 7 7 6 6 60 15 33 11 2 10 0 18361 Engineering - 0 0 0 0 0 0 0 0 0 0 0 0 062 Allocations - 0 0 0 0 0 0 0 0 0 0 0 0 063 Other 60 9 2 2 2 2 20 5 11 4 1 3 0 6064 Contingency - 0 0 0 0 0 0 0 0 0 0 0 0 0

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2018 2019

Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Total Jan Feb Mar Apr May June Total


Page: 1 of 1

2018 2019


2 2 1 4 8 16 14 17 11 12 11 8 108 1 1 1 2 4 9 8 10 6 7 6 5 600 0 0 0 0 0 0 0 0 0 0 0 01 0 0 1 2 4 3 4 3 3 3 2 260 0 0 0 0 0 0 0 0 0 0 0 00 0 0 1 1 2 2 2 2 2 2 1 150 0 0 0 1 1 1 1 1 1 1 1 70 0 0 0 0 0 0 0 0 0 0 0 0


Page: 1 of 1

2018 2019


26 23 16 48 90 175 157 194 122 135 128 93 1,208 14 13 9 27 50 98 88 108 68 75 71 52 672

0 0 0 0 0 0 0 0 0 0 0 0 07 6 4 12 23 46 41 51 32 35 33 24 3150 0 0 0 0 0 0 0 0 0 0 0 04 3 2 7 13 25 22 27 17 19 18 13 1701 1 1 2 4 7 7 8 5 6 5 4 500 0 0 0 0 0 0 0 0 0 0 0 0

8 7 5 16 29 57 51 63 40 44 42 30 392 2 2 1 3 7 13 11 14 9 10 9 7 885 5 3 10 18 36 32 39 25 28 26 19 2461 1 1 2 3 6 6 7 4 5 5 3 430 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 1 2 1 2 1 1 1 1 110 0 0 0 0 1 1 1 1 1 1 0 50 0 0 0 0 0 0 0 0 0 0 0 0

25 22 15 46 87 169 3656 5 4 11 21 41 88

15 14 9 29 54 105 2262 2 1 4 8 16 350 0 0 0 0 0 01 1 0 1 3 5 110 0 0 1 1 2 50 0 0 0 0 0 0

60 59 136 164 168 234 203 273 227 201 162 151 20400 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0

18 17 40 48 49 69 60 80 67 59 48 45 6001 1 3 3 3 5 4 5 4 4 3 3 40

41 41 93 113 115 161 139 188 156 138 111 104 14000 0 0 0 0 0 0 0 0 0 0 0 0


Page: 1 of 1

2018 2019


40 36 25 75 141 274 5910 0 0 0 0 0 00 0 0 0 0 0 00 0 0 0 0 0 0

27 24 17 51 95 186 4009 8 6 17 32 63 1364 3 2 7 13 26 550 0 0 0 0 0 0

24 21 15 45 84 163 147 181 113 126 120 87 1,124 7 6 4 13 24 47 42 52 33 37 35 25 3268 7 5 15 29 56 50 62 39 43 41 30 3840 0 0 0 1 2 2 2 1 1 1 1 121 1 1 2 3 6 5 6 4 4 4 3 401 1 1 2 3 6 5 6 4 4 4 3 393 3 2 6 11 22 20 24 15 17 16 12 1504 3 2 7 13 25 23 28 18 19 18 13 173

0 0 0 0 1 1 1 2 1 1 1 1 10 24 21 15 45 84 163 3510 0 0 0 0 0 0 0 0 0 0 0 0 11 9 6 19 37 71 1540 0 0 0 0 0 0 0 0 0 0 0 0 8 7 5 15 28 55 1190 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 2 40 0 0 0 1 1 1 2 1 1 1 1 10 1 1 1 2 3 6 120 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 2 3 6 120 0 0 0 0 0 0 0 0 0 0 0 0 3 3 2 6 12 23 500 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

25 22 15 46 87 170 153 189 119 132 125 91 1,174 7 6 4 13 24 47 42 52 33 36 34 25 3249 8 6 17 33 64 57 70 44 49 47 34 4380 0 0 0 1 2 2 2 1 1 1 1 121 1 1 2 3 6 5 6 4 4 4 3 401 1 1 2 3 6 5 6 4 4 4 3 393 3 2 6 11 22 20 24 15 17 16 12 1504 3 2 7 13 25 22 28 17 19 18 13 171


Page: 1 of 1

2018 2019


23 20 14 43 80 156 140 173 109 121 115 83 1,078 8 7 5 15 27 53 48 59 37 41 39 28 3677 7 5 14 26 51 46 56 35 39 37 27 3500 0 0 0 1 2 1 2 1 1 1 1 111 1 0 1 3 5 5 6 4 4 4 3 361 1 0 1 3 5 5 6 4 4 4 3 363 2 2 5 9 17 16 19 12 13 13 9 1203 3 2 6 12 23 21 25 16 18 17 12 158

43 38 26 79 148 289 260 320 201 223 212 154 1,991 15 13 9 27 51 99 89 110 69 77 73 53 68514 12 8 26 49 95 85 105 66 73 69 50 652

1 0 0 1 2 4 3 4 3 3 3 2 262 2 1 3 6 12 11 13 8 9 9 6 842 2 1 3 6 12 11 13 8 9 9 6 834 4 3 8 15 29 26 32 20 22 21 15 2006 5 3 10 19 38 34 42 26 29 28 20 262

27 24 16 50 94 184 165 204 128 142 135 98 1,269 9 8 6 17 33 64 58 71 45 50 47 34 4429 8 5 17 31 61 55 67 42 47 45 32 4190 0 0 1 1 2 2 3 2 2 2 1 171 1 1 2 4 8 7 9 5 6 6 4 541 1 1 2 4 8 7 9 5 6 6 4 542 2 1 4 7 15 13 16 10 11 11 8 1004 4 2 7 14 27 24 30 19 21 20 14 185

27 24 16 50 94 184 165 204 128 142 135 98 1,269 9 8 6 17 33 64 58 71 45 50 47 34 4429 8 5 17 31 61 55 67 42 47 45 32 4190 0 0 1 1 2 2 3 2 2 2 1 171 1 1 2 4 8 7 9 5 6 6 4 541 1 1 2 4 8 7 9 5 6 6 4 542 2 1 4 7 15 13 16 10 11 11 8 1004 4 2 7 14 27 24 30 19 21 20 14 185

28 25 17 52 97 190 170 210 132 147 139 101 1,308 9 8 6 18 33 64 58 71 45 50 47 34 4438 7 5 15 28 54 49 60 38 42 40 29 3730 0 0 1 2 3 3 3 2 2 2 2 201 1 1 3 5 10 9 11 7 7 7 5 671 1 1 3 5 10 9 11 7 7 7 5 663 3 2 6 11 22 20 24 15 17 16 12 1504 4 2 7 14 27 25 30 19 21 20 15 189


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2018 2019


28 25 17 52 97 189 170 209 131 146 138 101 1,301 10 9 6 18 34 65 59 72 45 51 48 35 451

9 8 6 17 32 63 57 70 44 49 46 34 4370 0 0 1 1 2 2 3 2 2 2 1 161 1 1 2 4 8 7 9 6 6 6 4 551 1 1 2 4 8 7 9 6 6 6 4 552 2 1 4 7 15 13 16 10 11 11 8 1004 4 2 7 14 27 25 30 19 21 20 15 188

0 0 0 1 1 3 3 3 2 2 2 2 20 27 24 16 50 94 183 3950 0 0 0 0 0 0 0 0 0 0 0 0 10 9 6 18 34 65 1410 0 0 0 0 0 0 0 0 0 0 0 0 9 8 6 17 32 63 1360 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 2 50 0 0 1 1 3 3 3 2 2 2 2 20 1 1 1 2 4 8 170 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 2 4 8 170 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 3 5 9 200 0 0 0 0 0 0 0 0 0 0 0 0 4 4 2 7 14 27 59

0 0 0 1 1 3 3 3 2 2 2 2 20 31 27 19 57 106 207 4460 0 0 0 0 0 0 0 0 0 0 0 0 11 10 7 20 38 74 1600 0 0 0 0 0 0 0 0 0 0 0 0 11 9 6 20 37 72 1550 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 3 60 0 0 1 1 3 3 3 2 2 2 2 20 1 1 1 2 5 9 200 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 2 5 9 190 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 3 5 9 200 0 0 0 0 0 0 0 0 0 0 0 0 5 4 3 8 16 31 67

0 0 0 1 1 3 60 0 0 0 0 0 00 0 0 0 0 0 00 0 0 0 0 0 00 0 0 1 1 3 60 0 0 0 0 0 00 0 0 0 0 0 00 0 0 0 0 0 0

0 0 0 1 1 3 3 3 2 2 2 2 20 31 27 19 57 106 207 4460 0 0 0 0 0 0 0 0 0 0 0 0 11 10 7 20 38 74 1600 0 0 0 0 0 0 0 0 0 0 0 0 11 9 6 20 37 72 1550 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 3 60 0 0 1 1 3 3 3 2 2 2 2 20 1 1 1 2 5 9 200 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 2 5 9 190 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 3 5 9 200 0 0 0 0 0 0 0 0 0 0 0 0 5 4 3 8 16 31 67


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2018 2019


21 19 13 39 73 142 128 158 99 110 104 76 982 6 5 3 10 19 38 34 42 26 29 28 20 2627 6 4 12 23 45 40 49 31 35 33 24 3080 0 0 0 1 1 1 2 1 1 1 1 101 1 0 1 2 5 4 5 3 4 3 2 321 1 0 1 2 5 4 5 3 4 3 2 324 4 3 8 15 29 26 32 20 22 21 15 2003 3 2 5 10 20 18 22 14 16 15 11 139

3 3 2 6 11 21 19 23 15 16 15 11 144 1 1 1 2 5 9 8 10 6 7 7 5 610 0 0 0 0 0 0 0 0 0 0 0 01 1 0 1 2 5 4 5 3 4 3 3 330 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 1 1 1 2 1 1 1 1 101 1 1 2 3 6 5 6 4 4 4 3 400 0 0 0 0 0 0 0 0 0 0 0 0

1 1 1 3 5 10 9 11 7 8 7 5 70 1 1 0 1 2 4 4 5 3 3 3 2 300 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 1 1 1 2 1 1 1 1 100 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 1 1 1 1 1 1 0 51 0 0 1 2 4 3 4 2 3 3 2 250 0 0 0 0 0 0 0 0 0 0 0 0

7 6 4 14 25 50 45 55 35 38 36 26 342 3 3 2 6 11 21 19 23 14 16 15 11 1430 0 0 0 0 0 0 0 0 0 0 0 02 1 1 3 6 11 10 12 8 9 8 6 760 0 0 0 0 0 0 0 0 0 0 0 01 0 0 1 2 3 3 4 2 3 3 2 242 2 1 4 7 15 13 16 10 11 11 8 1000 0 0 0 0 0 0 0 0 0 0 0 0

2 2 1 4 7 14 13 16 10 11 10 8 98 1 1 1 2 3 6 5 6 4 4 4 3 400 0 0 0 0 0 0 0 0 0 0 0 00 0 0 1 1 3 3 3 2 2 2 2 200 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 1 1 1 2 1 1 1 1 101 1 0 1 2 4 4 5 3 3 3 2 280 0 0 0 0 0 0 0 0 0 0 0 0


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2018 2019


4 3 2 7 13 25 22 28 17 19 18 13 172 2 1 1 3 5 10 9 11 7 8 7 5 700 0 0 0 0 0 0 0 0 0 0 0 01 1 0 1 3 5 5 6 4 4 4 3 350 0 0 0 0 0 0 0 0 0 0 0 00 0 0 1 1 3 2 3 2 2 2 1 181 1 1 2 4 7 6 8 5 6 5 4 490 0 0 0 0 0 0 0 0 0 0 0 0

4 4 3 8 14 28 25 31 20 22 21 15 194 2 2 1 3 6 11 10 13 8 9 8 6 790 0 0 0 0 0 0 0 0 0 0 0 01 1 1 2 3 6 5 6 4 4 4 3 400 0 0 0 0 0 0 0 0 0 0 0 00 0 0 1 1 3 3 3 2 2 2 2 201 1 1 2 4 8 7 9 6 6 6 4 550 0 0 0 0 0 0 0 0 0 0 0 0

11 10 7 20 38 75 1602 2 1 4 7 14 312 2 1 3 6 12 261 1 1 2 4 8 180 0 0 0 0 0 01 1 1 2 4 7 151 1 1 3 5 9 203 3 2 6 12 24 51

24 21 15 44 83 162 146 180 113 125 119 87 1,119 5 4 3 8 16 31 28 34 21 24 22 16 212

14 12 8 26 49 95 85 105 66 73 69 50 6531 1 1 2 3 6 6 7 4 5 4 3 421 1 1 2 3 6 6 7 4 5 4 3 423 3 2 6 11 21 19 24 15 17 16 11 1480 0 0 1 2 3 3 3 2 2 2 2 210 0 0 0 0 0 0 0 0 0 0 0 0

24 21 14 44 82 161 3465 4 3 8 16 31 67

14 13 9 26 49 96 2061 1 1 2 3 6 131 1 1 2 3 6 133 3 2 6 11 22 470 0 0 0 0 0 00 0 0 0 0 0 0


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2018 2019


80 71 49 149 280 545 490 604 379 421 400 291 3,759 15 14 9 28 53 103 93 114 72 80 76 55 71247 42 28 87 163 318 286 353 221 246 233 170 2194

3 3 2 6 11 21 19 23 14 16 15 11 1423 3 2 6 11 21 19 23 14 16 15 11 142

11 9 6 20 37 72 65 80 50 56 53 38 4982 1 1 3 5 10 9 11 7 8 8 5 710 0 0 0 0 0 0 0 0 0 0 0 0

74 66 45 137 257 501 107915 14 9 28 53 104 22443 38 26 79 149 291 627

3 2 2 5 10 19 413 2 2 5 10 19 41

10 9 6 18 34 66 1420 0 0 1 1 2 50 0 0 0 0 0 0

21 19 13 39 74 144 129 160 100 111 106 77 993 5 4 3 9 17 33 30 37 23 26 24 18 229

11 9 6 20 37 72 64 79 50 55 53 38 4941 1 1 2 3 7 6 7 5 5 5 3 451 1 1 2 3 7 6 7 5 5 5 3 453 3 2 6 12 23 21 25 16 18 17 12 1570 0 0 1 2 3 3 4 2 3 2 2 220 0 0 0 0 0 0 0 0 0 0 0 0

313 306 703 850 872 1,215 1,053 1,417 1,176 1,042 839 784 1057063 61 141 170 174 243 211 283 235 208 168 157 211475 73 169 204 209 292 253 340 282 250 201 188 253772 70 162 196 200 279 242 326 271 240 193 180 243131 31 70 85 87 121 105 142 118 104 84 78 1057

9 9 21 26 26 36 32 43 35 31 25 24 31763 61 141 170 174 243 211 283 235 208 168 157 2114

0 0 0 0 0 0 0 0 0 0 0 0 0

89 79 54 165 310 605 543 670 421 467 443 322 4,169 17 15 10 31 59 115 103 127 80 89 84 61 79152 46 32 97 181 354 318 392 246 273 259 189 2440

3 3 2 6 12 23 21 25 16 18 17 12 1583 3 2 6 12 23 21 25 16 18 17 12 158

12 10 7 22 41 80 72 89 56 62 59 43 5531 1 1 3 5 10 9 11 7 8 7 5 690 0 0 0 0 0 0 0 0 0 0 0 0


Page: 1 of 1

2018 2019


26 23 16 48 91 178 160 197 124 137 130 95 1,224 18 16 11 33 61 120 107 132 83 92 88 64 824

0 0 0 0 0 0 0 0 0 0 0 0 06 6 4 12 22 44 39 48 30 34 32 23 3000 0 0 0 0 0 0 0 0 0 0 0 02 2 1 4 7 15 13 16 10 11 11 8 1000 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0

0 0 0 1 1 3 60 0 0 0 0 0 00 0 0 0 0 0 00 0 0 0 0 0 00 0 0 1 1 2 50 0 0 0 0 0 10 0 0 0 0 0 00 0 0 0 0 0 0

0 0 0 1 1 3 60 0 0 0 0 0 00 0 0 0 0 0 00 0 0 0 0 0 00 0 0 1 1 2 50 0 0 0 0 0 10 0 0 0 0 0 00 0 0 0 0 0 0

0 0 0 1 1 3 60 0 0 0 0 0 00 0 0 0 0 0 00 0 0 0 0 0 00 0 0 1 1 2 50 0 0 0 0 0 10 0 0 0 0 0 00 0 0 0 0 0 0

0 0 0 1 1 3 60 0 0 0 0 0 00 0 0 0 0 0 00 0 0 0 0 0 00 0 0 1 1 2 50 0 0 0 0 0 10 0 0 0 0 0 00 0 0 0 0 0 0


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2018 2019


41 36 25 76 142 277 249 307 192 214 203 147 1,907 8 7 5 14 27 52 47 58 36 40 38 28 361

24 21 14 44 83 161 145 179 112 125 118 86 11132 1 1 3 5 10 9 12 7 8 8 6 722 1 1 3 5 10 9 12 7 8 8 6 725 5 3 10 19 37 33 41 25 28 27 20 2531 1 0 1 3 5 5 6 4 4 4 3 360 0 0 0 0 0 0 0 0 0 0 0 0

175 171 393 475 487 679 589 792 658 582 469 438 590835 34 79 95 97 136 118 158 132 116 94 88 118242 41 94 114 117 163 141 190 158 140 113 105 141840 39 90 109 112 156 135 182 151 134 108 101 135917 17 39 48 49 68 59 79 66 58 47 44 591

5 5 12 14 15 20 18 24 20 17 14 13 17735 34 79 95 97 136 118 158 132 116 94 88 1182

0 0 0 0 0 0 0 0 0 0 0 0 0

512 501 1152 1392 1427 1989 6974102 100 230 278 285 398 1395123 120 276 334 343 477 1674118 115 265 320 328 458 1604

51 50 115 139 143 199 69715 15 35 42 43 60 209

102 100 230 278 285 398 13950 0 0 0 0 0 0


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2018 2019


35 31 21 65 123 239 215 265 167 185 175 128 1,651 0 0 0 0 0 0 0 0 0 0 0 0 0

20 18 12 37 69 134 120 148 93 104 98 71 9238 7 5 15 27 54 48 59 37 41 39 29 3690 0 0 0 0 0 0 0 0 0 0 0 04 4 2 7 14 27 24 30 19 21 20 14 1854 3 2 7 13 25 23 28 18 19 18 13 1740 0 0 0 0 0 0 0 0 0 0 0 0

19 17 12 36 68 132 28411 9 6 20 37 72 155

5 4 3 9 16 32 680 0 0 0 0 0 02 2 1 4 7 14 312 2 1 4 7 14 290 0 0 0 0 0 00 0 0 0 0 0 0

133 118 81 246 463 903 194426 23 16 47 89 174 37479 70 48 146 275 536 1154

5 5 3 9 18 35 755 5 3 9 18 35 75

18 16 11 33 62 122 2620 0 0 1 1 2 50 0 0 0 0 0 0

133 118 81 246 463 903 194426 23 16 47 89 174 37479 70 48 146 275 536 1154

5 5 3 9 18 35 755 5 3 9 18 35 75

18 16 11 33 62 122 2620 0 0 1 1 2 50 0 0 0 0 0 0


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2018 2019


135 120 82 250 469 914 196926 23 16 48 90 176 37980 71 49 148 278 543 1169

5 5 3 10 18 35 765 5 3 10 18 35 76

18 16 11 34 63 123 2650 0 0 1 1 2 50 0 0 0 0 0 0

141 125 86 261 491 958 206274 66 45 138 259 505 1088

0 0 0 0 0 0 032 29 20 60 112 219 472

0 0 0 0 0 0 019 17 11 34 65 126 27216 14 10 29 55 107 230

0 0 0 0 0 0 0

2193 2146 4935 5965 6115 8523 29876439 429 987 1193 1223 1705 5975526 515 1184 1432 1468 2046 7170504 494 1135 1372 1406 1960 6872219 215 493 596 611 852 2988

66 64 148 179 183 256 896439 429 987 1193 1223 1705 5975

0 0 0 0 0 0 0

362 354 814 984 1009 1407 493168 67 154 186 191 266 933

211 207 475 575 589 821 287914 13 31 37 38 53 18714 13 31 37 38 53 18748 47 108 130 134 186 653

7 7 15 19 19 27 930 0 0 0 0 0 0

41 40 92 111 114 159 5588 8 18 22 23 32 112

10 10 22 27 27 38 1349 9 21 26 26 37 1284 4 9 11 11 16 561 1 3 3 3 5 178 8 18 22 23 32 1120 0 0 0 0 0 0


Page: 1 of 1

2018 2019


216 211 486 587 602 839 294043 42 97 117 120 168 58852 51 117 141 144 201 70550 49 112 135 138 193 67622 21 49 59 60 84 294

6 6 15 18 18 25 8843 42 97 117 120 168 588

0 0 0 0 0 0 0

26 23 16 48 91 177 38212 11 7 23 43 84 180

0 0 0 0 0 0 09 8 5 16 30 58 1255 5 3 10 18 35 750 0 0 0 0 1 20 0 0 0 0 0 00 0 0 0 0 0 0


Page: 1 of 1

2018 2019



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U-18424Attachment 11, Filing Requirement #6

6. In 2016 Consumers Energy capitalized 151 of 179 digs (84%) with pipe replacement greater than 50’.Additionally in 2016 Consumers Energy capitalized 16 remediation digs with new coating replacement greater than 50 sq.ft.with no pipe replacement.In total 167 of 179 digs were capitalized, (93%)a. The attached dig summary report contains explanations as to the necessity of replacing the footage with each dig.

U-18424

Attachment 11, Filing Requirement #6


Capital Dig HCA County Township Pup Size (ft) Description Capital Justification Anomaly Type

GL-00689 GL-00690 STC-600 Clrkstn to Squirrel Rd

26660983 STC-600 Clrkstn Jct-Squirrel O- General

26663499 STC-600 Clrkstn Jct-Squirrel C- General

25877331 STC-600 Clrkstn Jct-Squirrel C-Dig 2 Capital No Oakland Rose 66.25

Removed and installed 66.25' of 22" O.D. x 0.375" W.T., ERW-HFW-HFW, API5L X-65, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #25877331, Kathryn Maloney)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. External Anomaly along with Seam Weld Anomaly noted in adjacent joints of pipe. EXTERNAL CLUSTER

25877420 STC-600 Clrkstn Jct-Squirrel C-Dig 8 Capital No Oakland Springfield 58.88

Removed and installed 58.88' of 22" O.D. x 0.375" W.T., ERW-HFW, API5L X-65, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #25877420, Kathryn Maloney)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT near seam weld



Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Attachment Patch?



Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Attachment along with Seam Weld Manufacturing Anomalies in adjacent joints of pipe. Attachment



Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. External cluster in a wetland area, entire length of pipe through this wetland was replaced. EXTERNAL CLUSTER

25877428 STC-600 Clrkstn Jct-Squirrel C-Dig 16 Capital No Oakland Independence 52.55


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT near girth weld

25877430 STC-600 Clrkstn Jct-Squirrel C-Dig 18 Capital No Oakland Independence 60

Removed and installed 60' of 22" O.D. x 0.375" W.T., ERW-HFW, API5L X-65, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #25877430, Kathryn Maloney)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld ML Manufacturing anomaly and Seam Weld Anomaly in SEAM WELD ML MANUFACTURING ANOMALY

25877432 STC-600 Clrkstn Jct-Squirrel C-Dig 20 Capital Yes Oakland Independence 119.31


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld ML Manufacturing anomalies in adjacent joints and also located near roadway and driveway. SEAM WELD ML MANUFACTURING ANOMALY

25877433 STC-600 Clrkstn Jct-Squirrel C-Dig 21 Capital Yes Oakland Independence 52.95


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT near girth weld

25877437 STC-600 Clrkstn Jct-Squirrel C-Dig 25 Capital No Oakland Orion 55.25


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. ML MANUFACTURING ANOMALY

25877439 STC-600 Clrkstn Jct-Squirrel C-Dig 26 Capital Yes Oakland Orion 58.07


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT

971.43

GL-00695 GL-00696 OVC-1100 Mdlvle to Clntonia

26663825 OVR-1100 MdlvleCal to Clintonia C-REM

27468294 OVR-1100 MdlvleCal to Clintonia C-REM 4 - 2016 Capital No BARRY IRVING 50.91

Removed and installed 50.91' of 24" O.D. x 0.375" W.T., ERW-HFW, API5L X-65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27468294, Pete Pryson)

Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. ML MANUFACTURING ANOMALY



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. 4.0D Overbend at this dig, required additional pipe to be removed. ML MANUFACTURING ANOMALY

27468298 OVR-1100 MdlvleCal to Clintonia C-REM 9 - 2016 Capital No BARRY CARLTON 69.79



27468299 OVR-1100 MdlvleCal to Clintonia C-REM 12 - 2016 Capital No BARRY WOODLAND 91.09


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. 2.0D Overbend at this dig, required additional pipe to be removed. ML MANUFACTURING ANOMALY

27468540 OVR-1100 MdlvleCal to Clintonia C-REM 13 - 2016 Capital No BARRY WOODLAND 51.64


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT

27468541 OVR-1100 MdlvleCal to Clintonia C-REM 15 - 2016 Capital No EATON SUNFIELD 51.53



2016 REMEDIATION DIG SUMMARY

U-18424







Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. EXTERNAL CLUSTER



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Additional pipe removed in order to find a good tie-in point for welding. Attachment welded?

27468544 OVR-1100 MdlvleCal to Clintonia C-REM 18 - 2016 Capital No IONIA DARBY 106.66


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Internal corrosion on adjacent joints of pipe, additional pipe removed. INTERNAL CLUSTER

677.30

GL-01027 GL-01028 SAG-500 Ovid to Grand Blanc Pre-70's EFW

26660986 SAG-500 Ovid to Grand Blanc O-REM

26663828 SAG-500 Ovid to Grand Blanc C-REM

25180272 SAG-500 Ovid to Grand Blanc C--Dig 6 Capital No Shiawassee Middlebury 53.05

Removed and installed 53.05' of 26" O.D. x 0.375" W.T.,DSAW, API5L X-65, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #25180272, Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT

25180273 SAG-500 Ovid to Grand Blanc C--Dig 7 Capital No Shiawassee Middlebury 51.14


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed.

DEFORMATION ANOMALY-DENT Associated with Girth Weld

27186694 SAG-500 Ovid to Grand Blanc C--Dig 14 Capital No Shiawassee Shiawassee 51.5
















Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. A dent and Manufacturing anomalies on multiple joints of pipe.


25181071 SAG-500 Ovid to Grand Blanc C--Dig 22 Capital No Shiawassee Vernon 52.48



25181078 SAG-500 Ovid to Grand Blanc C--Dig 27 Capital No Genesee Mundy 51.07


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SEAM WELD ML MANUFACTURING ANOMALY

25181079 SAG-500 Ovid to Grand Blanc C--Dig 28 Capital No Genesee Mundy 61.29


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld Metal Loss Anomaly. SEAM WELD ML MANUFACTURING ANOMALY

556.26

GL-00685 GL-00686 SAG-300 ClmnBvrtn to Midland Pre-70 ERW

26661165 SAG-300 ClmnBvrtn to Midland O-REM

26663487 SAG-300 ClmnBvrtn to Midland C-REM

25333661 SAG-300 ClmnBvrtn to Midland C-Dig8 Capital No Midland Warren 58.92

Removed and installed 58.92' of 12.75" O.D. x 0.250" W.T.,ERW-HFW, API5L X-52, FBE Coated Pipe hydrotested to 1450 +/- 25 psig - 2016 Pipeline Remediation (SAP #25333661, Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. EXTRA METAL near seam weld

27633200 25333662 SAG-300 ClmnBvrtn to Midland C-Dig9 O&M No Midland Warren 0.00 Verification Dig, No Pipe Replacement Attachment

25333664 SAG-300 ClmnBvrtn to Midland C-Dig10 Capital No Midland Warren 50.16


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Sleeve

25333669 SAG-300 ClmnBvrtn to Midland C-Dig15 Capital No Midland Jerome 51.60


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SEAM WELD DENT

25333587 27633203 SAG-300 ClmnBvtn to Midland O-REM 17 Capital No Midland Jerome 51.15



25333672 SAG-300 ClmnBvrtn to Midland C-Dig19 Capital No Midland Jerome 54.73



U-18424





25333589 27633205 SAG-300 ClmnBvtn to Midland O-REM 20 Capital No Midland Lee 717.34


Existing pipe was Pre-70's ERW. The target anomaly on this dig was in the middle of a wetland, which also contained a water hole that happened to be right where Dig 20 was located. To get to this location we had to place mats through the entire wetland and de-water the entire wetland. In doing so, the decision was made to replace the entire segment through the wetland, from the high ground downstream and upstream of the dig site.

DEFORMATION ANOMALY-DENT near seam weld

25333673 SAG-300 ClmnBvrtn to Midland C-Dig21 Capital No Midland Lee 51.35


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT Assoc. with Field Bend

25333676 SAG-300 ClmnBvrtn to Midland C-Dig23 Capital No Midland Lee 51.30


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT Assoc. with Girth Weld

1086.55

GL-01038 GL-01039 SAG-100A Airport Rd to Muskegon - 2015 Rollover Work Pre 70's ERW

26661162 SAG 100A Airport Rd to Muskegon O-REM General

26663830 SAG 100A Airport Rd to Muskegon C-REM General

27165233 SAG 100A Airport Rd to Muskegon C-REM Dig #2 Capital No ISABELLA UNION 57.7

Removed and installed 57.7' of 22" O.D. x 0.375" W.T.,ERW-HFW, API5L X-60, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27165233, Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SEAM WELD MANUFACTURING ANOMALY

27165234 SAG 100A Airport Rd to Muskegon C-REM Dig #3 Capital No ISABELLA UNION 105.45


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld ML Manufacturing and external corrosion in adjacent joints of pipe. SEAM WELD ML MANUFACTURING ANOMALY

27165235 SAG 100A Airport Rd to Muskegon C-REM Dig #6 Capital No ISABELLA ISABELLA 104.36

Removed and installed 104.36' of 22" O.D. x 0.375" W.T.,ERW-HFW, API5L X-60 & X-65, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27165235, Mitch

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. External corrosion in adjacent joints of pipe. EXTERNAL CLUSTER






Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Sean Weld ML Manufacturing and corrosion in joint of pipe. SEAM WELD ML MANUFACTURING ANOMALY



Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. EXTERNAL CLUSTER



Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Corrosion and SWML Manufacturing in adjacent joints of pipe. SEAM WELD ML MANUFACTURING ANOMALY


Removed and installed 204.94' of 22" O.D. x 0.375" W.T.,ERW-HFW, API5L X-60 & X-65, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27165441, Mitch

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SWML Manufacturing in adjacent joints of pipe. SEAM WELD ML MANUFACTURING ANOMALY





Removed and installed 101.75' of 22" O.D. x 0.375" W.T.,ERW-HFW, API5L X-60,X42/X52 FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27165443, Mitch

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Located in an MDEQ creek, additional pipe replaced due to creek. DEFORMATION ANOMALY-DENT






Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Dent along with ML Manufacturing Anomaly.

DEFORMATION ANOMALY-DENT associated with field bend

27165447 SAG 100A Airport Rd to Muskegon C-REM Dig #32 Capital No ISABELLA VERNON 98.92


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. 5.0D Overbend and a 3.0D Sag were needed at this dig site, additional pipe removed. SEAM WELD ML MANUFACTURING ANOMALY


Removed and installed 54.73' of 22" O.D. x 0.375" W.T.,ERW-HFW, API5L X42 & X65, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27165448, Mitch Loomis)



Removed and installed 71.84' of 22" O.D. x 0.375" W.T.,ERW-HFW, API5L X-60 & X-65 FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27165449, Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld ML Manufacturing anomalies in adjacent joints of pipe. SEAM WELD ML MANUFACTURING ANOMALY

27813630 27165450 SAG 100A Airport Rd to Muskegon C-REM Dig #35 O&M No ISABELLA VERNON 0Verification Dig, No Pipe Replacement (SAP #27813630, Mitch Loomis) Attachment



Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Additional pipe removed for pipe tie-in (laminations). EXTERNAL CLUSTER

27276616 SAG 100A Airport Rd to Muskegon C-REM Dig #42A Capital No ISABELLA VERNON 76.12

Removed and installed 76.12' of 22" O.D. x 0.375" W.T.,ERW-HFW, API5L X-60 & X-65, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27276616, Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. External corrosion. EXTERNAL CLUSTER

U-18424







Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. 4.3D bend required, additional pipe removed. SEAM WELD MANUFACTURING ANOMALY




27276617 SAG 100A Airport Rd to Muskegon C-REM Dig #44A Capital No ISABELLA GRANT 55.38


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. EXTERNAL CLUSTER

27165454 SAG 100A Airport Rd to Muskegon C-REM Dig #45 Capital No CLARE GRANT 102.68


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld Manufacturing and external corrosion in adjacent joints of pipe. SEAM WELD MANUFACTURING ANOMALY

27165455 SAG 100A Airport Rd to Muskegon C-REM Dig #46 Capital No CLARE GRANT 72.88

Removed and installed 57.7' of 22" O.D. x 0.375" W.T.,ERW-HFW, API5L X-60 & X-65 FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27165455, Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld ML Manufacturing and Seal Weld Manufacturing in adjacent joints of pipe. SEAM WELD ML MANUFACTURING ANOMALY

25641703 SAG 100A Airport Rd to Muskegon C-REM Dig #48 Capital No CLARE SURREY 89.15


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld ML Manufacturing and Seam Weld Manufacturing in adjacent joints of pipe. SEAM WELD MANUFACTURING ANOMALY

27165456 SAG 100A Airport Rd to Muskegon C-REM Dig #59 Capital No CLARE GREENWOOD 55.9



27165457 SAG 100A Airport Rd to Muskegon C-REM Dig #60 Capital No CLARE GREENWOOD 103.96


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Difficult dig location due to water and sub surface soil conditions. Attachment Possible puddle weld repair

27165458 SAG 100A Airport Rd to Muskegon C-REM Dig #61 Capital No CLARE REDDING 139.74


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. 3.3D bend plus problems finding a good tie-in point required more pipe to be replaced.

DEFORMATION ANOMALY-DENT associated with girth weld

27165459 SAG 100A Airport Rd to Muskegon C-REM Dig #65 Capital No CLARE WINTERFIELD 66.66


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Joint of pipe with attachment removed. Attachment Possible puddle weld repair

2284.12

GL-01565 GL-01566 SAG-100A Airport Rd to Muskegon - EMAT Digs Pre-70's ERW

26583801 SAG 100A Airport Rd to Muskegon O-REM General

26599300 SAG 100A Airport Rd to Muskegon C-REM General

27544740 SAG 100A Airport Rd to Muskegon C-EMAT #1 Capital Isabella Union 100.36

Removed and installed 100.36' of 22" O.D. x 0.375" W.T., ERW-HFW, API5L X-60, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27544740,Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Longitudinal weld anomaly joint removed.

Longitudinal weld anomaly



Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Longitudinal weld anomaly joint removed along with adjacent Seam Weld Manufacturing.




Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Longitudinal weld anomaly joint removed.


27544744 SAG 100A Airport Rd to Muskegon C-EMAT #4 Capital Isabella Isabella 125.09


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Longitudinal weld anomaly joint removed along with external corrosion.




Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear anomaly removed along with external corrosion.

Linear anomaly B



Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear longitudinal weld anomaly removed along with adjacent external corrosion near seam weld.

Linear longitudinal weld anomaly











Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Longitudinal weld anomaly removed along with seam weld manufacturing anomaly.


U-18424





27544751 SAG 100A Airport Rd to Muskegon C-EMAT #10 Capital Isabella Veron 52

Removed and installed 52' of 22" O.D. x 0.375" W.T., ERW-HFW, API5L X-52, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27544751,Mitch Loomis)


Linear anomaly A

27544752 SAG 100A Airport Rd to Muskegon C-EMAT #11 Capital Clare Surrey 52.19




27544753 SAG 100A Airport Rd to Muskegon C-EMAT #12 Capital Clare Lincoln 56.01







Linear anomaly B







Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Longitudinal weld anomalies removed along with ML Manufacturing anomaly.


27544757 SAG 100A Airport Rd to Muskegon C-EMAT #16 Capital Clare Redding 55.62



Linear anomaly A

1144.79

GL-01294 100A - Chelsea to Ovid Pre-70's EFW

27092094 FDM-100A Chelsea to Ovid C-REM-General

27092220 FDM-100A Chelsea to Ovid C-REM C-D1 Capital Washtenaw Sylvan 80.27

Removed and installed 65.20' of 20” x 0.375”, ERW-HFW, API5L-X42, FBE Coated Pipe hydrotested to 1300 +/- 25 psig and 15.07' of 20” x 0.375”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1300 +/- 25 psig - 2016 Pipeline Remediation (SAP #, Mitch Loomis)

Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear Anomaly B removed.

27092221 FDM-100A Chelsea to Ovid C-REM C-D2 Capital Washtenaw Sylvan 95.51

Removed and installed 95.51' of 20” x 0.375”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1300 +/- 25 psig - 2016 Pipeline Remediation (SAP # 27092221, Mitch Loomis)

Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear longitudinal weld anomaly removed.

27092222 FDM-100A Chelsea to Ovid C-REM C-D4 Capital Washtenaw Lyndon 54.96


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed.

27092223 FDM-100A Chelsea to Ovid C-REM C-D5 Capital Washtenaw Lyndon 125.61


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Extra Metal removed.

27092224 FDM-100A Chelsea to Ovid C-REM C-D6 Capital Livingston Unadilla 55.31





Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear longitudinal weld anomaly removed.







27092229 FDM-100A Chelsea to Ovid C-REM D-O1 Capital Ingham White Oak 96.49


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. External ML Corrosion removed and SW Manufacturing removed in multiple joints of pipe.

27092230 FDM-100A Chelsea to Ovid C-REM D-O2 Capital Ingham White Oak 59.88



27092231 FDM-100A Chelsea to Ovid C-REM D-O3 Capital Ingham Leroy 62.77


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Puddle weld removed.

27092232 FDM-100A Chelsea to Ovid C-REM D-O4 Capital Ingham Williamston 59.42



27092233 FDM-100A Chelsea to Ovid C-REM D-O5 Capital Ingham Williamston 51.14



U-18424





27092234 FDM-100A Chelsea to Ovid C-REM D-O6 Capital Ingham Williamston 0Verification Dig, No pipe replaced. Over 50 sq. ft of coating replaced (SAP # 27092234, Mitch Loomis) Over 50 sq. ft of new coating was installed.

27092236 FDM-100A Chelsea to Ovid C-REM D-O7 Capital Clinton Victor 51

Removed and installed 51' of 20” x 0.375”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1300 +/- 25 psig - 2016 Pipeline Remediation (SAP # 27092236, Mitch Loomis)


27092237 FDM-100A Chelsea to Ovid C-REM D-O8 CancelledCancel

led Cancelled Cancelled CancelledExisting pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed.

27092261 FDM-100A Chelsea to Ovid C-REM D-O9 Capital Clinton Ovid 90.96


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Multiple attachments removed.

1040.59

GL-01568 GL-01569 KZO-1200A Trunkln to WhtPigeon Pre-70's EFW

26583910 KZO-1200A Trunkln to WhtPigeon O-REM General

26599302 KZO-1200A Trunkln to WhtPigeon C-REM General

27813637 KZO-1200A Trunkln to WhtPigeon C-REM Dig #1 Capital NoSt Joseph

CountyWhite Pigeon

township 51.5

Removed and installed 51.5' of 26" x 0.438, DSAW (SAWL) API5LX60, 14 Mil Min FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27813637, Peter Pryson)

Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SEAM WELD ML MANUFACTURING ANOMALY


CountyWhite Pigeon

township 90.48


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Attachments along with adjacent extra metal removed. EXTRA METAL


CountyWhite Pigeon

township 52.14


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SEAM WELD ML MANUFACTURING ANOMALY


CountyWhite Pigeon

township 156.91


Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Corrosion along with adjacent ML Manufacturing Anomaly removed. EXTERNAL ML CORROSION

351.03

GL-01571 GL-01572 KZO-1200B Lutes to Moscow

26584230 KZO-1200B Lutes to Moscow O-REM General

26599307 KZO-1200B Lutes to Moscow C-REM General Capital Jackson Hanover 0Installed (8) 11.4" x 36" Clockspring Repair kits over dent - 2016 Pipeline Remediation (SAP #26599307, Peter Pryson) Over 50 sq. ft of new coating was installed.

GL-01591 GL-01592 STC-26 Puttygut Mainline Double Submerged

26591446 STC-26 Puttygut Mainline O-REM General

26599400 STC-26 Puttygut Mainline C-REM General

27633207 27393023 STC-26 Puttygut Mainline Dig 1 O&M No St. Clair Casco 0 Verification Dig, No pipe replaced Metal Loss External

27393024 STC-26 Puttygut Mainline Dig 2 Capital No St. Clair Casco 0 Verification Dig, No pipe replaced. Over 50 Sq. ft coating replaced Over 50 sq. ft of new coating was installed. Dent

27393025 STC-26 Puttygut Mainline Dig 3 Capital No St. Clair Casco 183.09

Removed and installed 183.09' of 26" O.D. x 0.688" W.T.,DSAW, API5L X-65, FBE Coated Pipe hydrotested to 2,215 +/- 25 psig - 2016 Pipeline Remediation (SAP #27393025, Kathryn Maloney)

Dig 3 was underneath Hessen Road and underneath a drain on the west side of the road. All pipe within the casing was removed and replaced, and extended out from the casing, road and drain for tie-in. Metal Loss Internal

27393030 STC-26 Puttygut Mainline Dig Tap Valve 4 (Capital due Capital No St. Clair Casco 13.59

Removed and installed 13.59' of 26" O.D. x 0.688" W.T.,DSAW, API5L X-65, FBE Coated Pipe hydrotested to 2,215 +/- 25 psig - 2016 Pipeline Remediation (SAP #27393030, Kathryn Maloney) Tap Valve Retirement

27393031 STC-26 Puttygut Mainline Dig Tap Valve 5 (Capital due Capital No St. Clair Casco 24.28

Removed and installed 24.28' of 26" O.D. x 0.688" W.T.,DSAW, API5L X-65, FBE Coated Pipe hydrotested to 2,215 +/- 25 psig - 2016 Pipeline Remediation (SAP #27393031, Kathryn Maloney) Tap Valve Retirement

220.96

GL-01596 GL-01595 FDM-400 Laingsburg to Fenton Pre 70's ERW

26591449 FDM-400 Laingsburg to Fenton O-REM General

26599401 FDM-400 Laingsburg to Fenton C-REM General

28374452 FDM-400 Laingsburg to Fenton C-REM Dig #2 Capital No Livingston Tyrone 95.13

Removed and installed 95.13' of 24” x 0.375”, ERW-HFW, API5L-X65M, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP # 28374452, Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Dent and adjacent extra metal removed. DEFORMATION ANOMALY-DENT

U-18424





28374453 FDM-400 Laingsburg to Fenton C-REM Dig #3 Capital Yes Livingston Tyrone 139.59


Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Dent and adjacent SWML Manufacturing anomaly removed.

DEFORMATION ANOMALY-DENT/ SEAM WELD ML MANUFACTURING ANOMALY

28374454 FDM-400 Laingsburg to Fenton C-REM Dig #4 Capital No Livingston Deerfield 120.91

Removed and installed 120.91' of 24” x 0.375”, ERW-HFW, API5L-X65M, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #28374454, Mitch Loomis)

Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld Anomaly B in a casing removed. SEAM WELD ANOMALY - B

29005172 28374457 FDM-400 Laingsburg to Fenton C-REM Dig #5 O&M No Livingston DeerfieldVerification

Only No pipe replacement, verification dig. ML MANUFACTURING ANOMALY

28374458 FDM-400 Laingsburg to Fenton C-REM Dig #7 Capital No Livingston DeerfieldPetrosleeve

installedInstalled 3' Petrosleeve - 2016 Pipeline Remediation (SAP # 28374458, Mitch Loomis) Over 50 sq. ft of new coating was installed. SEAM WELD ML MANUFACTURING ANOMALY

28374459 FDM-400 Laingsburg to Fenton C-REM Dig #11 Capital No Shiawassee Antrim 50.95



28374500 FDM-400 Laingsburg to Fenton C-REM Dig #12 Capital No Shiawassee Antrim 52.94



28374501 FDM-400 Laingsburg to Fenton C-REM Dig #17 Capital Yes Shiawassee PerryPetrosleeve

InstalledInstalled 3' Petrosleeve - 2016 Pipeline Remediation (SAP # 28374501, Mitch Loomis) Over 50 sq. ft of new coating was installed. SEAM WELD ML MANUFACTURING ANOMALY

28374502 FDM-400 Laingsburg to Fenton C-REM Dig #18 Capital No Shiawassee PerryVerification

Only No pipe replacement, over 50 sq. ft of coating replaced. Over 50 sq. ft of new coating was installed. EXTERNAL CLUSTER

28374503 FDM-400 Laingsburg to Fenton C-REM Dig #19 Capital No Shiawassee PerryPetrosleeve

InstalledInstalled 3' Petrosleeve - 2016 Pipeline Remediation (SAP # 28374503, Mitch Loomis) Over 50 sq. ft of new coating was installed. SEAM WELD ML MANUFACTURING ANOMALY

28374506 FDM-400 Laingsburg to Fenton C-REM Dig #25 Capital No Shiawassee SciotaClock Spring Installation

Installed Clock Spring repair sleeve - 2016 Pipeline Remediation (SAP # 28374506, Mitch Loomis) Over 50 sq. ft of new coating was installed. EXTERNAL ML CORROSION

459.52

GL-01597 GL-01598 NVL-1070 Northville to Sheldon Pre-70's ERW

26599402 NVL-1070 Northville to Sheldon C-REM General

27856888 NVL-1070 Northville to Sheldon C- Dig #1 Capital No Wayne Northville 55.7

Removed and installed 55.7' of 16" O.D. x 0.375" W.T.,ERW-HFW, API5L X-42, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27856888, Kathryn Maloney)


28348381 27856895 NVL-1070 Northville to Sheldon C- Dig #2 O&M No Wayne Northville 16.19

Removed and installed 16.19' of 16" O.D. x 0.375" W.T.,ERW-HFW, API5L X-42, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #28348381, Kathryn Maloney) SEAM WELD ML MANUFACTURING ANOMALY






Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SWML Manufacturing anomaly removed. SEAM WELD ML MANUFACTURING ANOMALY






Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SEAM WELD ANOMALY - A

27857054 NVL-1070 Northville to Sheldon C- Dig #7 Capital Yes Wayne Northville 54.64











Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Seam Weld Anomaly A and ML Manufacturing near seam weld SEAM WELD ANOMALY - A




27857255 NVL-1070 Northville to Sheldon C- Dig #12 Capital Yes Wayne Northville 55

Removed and installed 55' of 16" O.D. x 0.375" W.T.,ERW-HFW, API5L X-52, FBE Coated Pipe hydrotested to 1250 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857255, Kathryn Maloney)







Existing pipe was Pre-70's ERW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SWML Manufacturing anomaly removed along with adjacent ML Manufacturing anomaly near seam weld. SEAM WELD ML MANUFACTURING ANOMALY




U-18424





1008.61

GL-01602 GL-01601 SAG-1900 Atlas to Grand Blanc Pre-70's EFW

26591453 SAG-1900 Atlas to Grand Blanc O-REM General

26599403 SAG-1900 Atlas to Grand Blanc C-REM General

28326603 28143831 SAG-1900 Atlas to Grand Blanc C-REM - Dig #1 O&M Yes Genesee Grand Blanc 0 Verification dig, no pipe or coating replaced Attachment

28374209 28143832 SAG-1900 Atlas to Grand Blanc C-REM - Dig #2 O&M Yes Genesee Grand Blanc 0 Verification dig, no pipe or coating replaced EXTRA METAL

28374210 28143833 SAG-1900 Atlas to Grand Blanc C-REM - Dig #3 O&M Yes Genesee Grand Blanc 0 Verification dig, no pipe or coating replaced ML MANUFACTURING ANOMALY near seam weld

0

GL-01603 GL-01604 STC-2070 Dutton Rd to Coolidge Double Submerged

269591532 STC-2070 Dutton Rd to Coolidge O-REM General

26599404 STC-2070 Dutton Rd to Coolidge C-REM General

28181399 STC-2070 Dutton Rd to Coolidge C-Dig 1 Capital Yes Oakland Oakland 33.26

Removed and installed 33.26' of 36" O.D. x 0.532" W.T., X-65 DSAW, Coated Pipe hydrotested to 1100 +/- 25 psig - 2016 Pipeline Remediation (SAP #28181399, Mitch Loomis). Capitalized with Valve Retirement. INTERNAL CLUSTER

28181800 STC-2070 Dutton Rd to Coolidge C-Dig 2 Capital Yes Oakland Oakland 163.34

Removed and installed 163.34' of 36" O.D. x 0.532" W.T., X-65 DSAW, Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #28181800, Mitch Loomis)

Dig 2 was located underneath a drain. Pipe was removed and replaced, dig was extended out for tie-in. INTERNAL CLUSTER

28181801 STC-2070 Dutton Rd to Coolidge C-Dig 3 Deferred Yes Oakland Oakland Deferred Dig deferred to 2017 DEFORMATION ANOMALY-DENT

28181802 STC-2070 Dutton Rd to Coolidge C-Dig 4 Capital Yes Oakland Oakland 0Verification Dig, No pipe replaced. 5 1/2 feet of Coating was replaced Over 50 sq. ft of new coating was installed. EXTERNAL ML CORROSION

28665180 28181803 STC-2070 Dutton Rd to Coolidge C-Dig 5 O&M Yes Oakland Oakland 0 Verification Dig, No pipe replaced EXTERNAL ML CORROSION

28181804 STC-2070 Dutton Rd to Coolidge C-Dig 6 Deferred Yes Oakland Oakland Deferred Dig deferred to 2017 EXTRA METAL

196.60

GL-01608 GL-01607 STC-24 Ray Mainline East Seamless

26599407 STC-24 Ray Mainline East C-REM General

28374217 STC-24 Ray Mainline East C-REM Dig #1 Capital No Macomb Ray 56.16

Removed and installed 56.16' of 24" O.D. x 0.688" W.T., X-65 ERW-HFW, FBE Coated Pipe hydrotested to 2750 +/- 25 psig - 2016 Pipeline Remediation (SAP #28374217, Mitch Loomis)

Metal Loss Internal pit detected at over 80% using UT, along with many other areas of metal loss internal. Pipe was removed to confirm pit reading, and other areas of metal loss were also removed. Metal Loss Internal

28374218 STC-24 Ray Mainline East C-REM Dig #2 Capital No Macomb Ray 0 Verification Dig, No pipe replaced, 50 Sq. ft. of coating replaced. Over 50 sq. ft of new coating was installed. Metal Loss Internal

28374219 STC-24 Ray Mainline East C-REM Dig #3 Capital No Macomb Ray 0 Verification Dig, No pipe replaced, 50 Sq. ft. of coating replaced. Over 50 sq. ft of new coating was installed. Metal Loss Internal

56.16

GL-01610 GL-01612 FDM-10-2 Dwit to LnsngCGDwit Rd Pre 70's EFW

26591525 FDM-10-2 Dwit to LnsngCGDwit Rd O-REM General26599408 FDM-10-2 Dwit to LnsngCGDwit Rd C-REM General

27544759 FDM-10-2 Dwit to LnsngCGDwit Rd C-EMAT #1 Capital No Clinton Dewitt 88.72

Removed and installed 88.72' of 20" x 0.344", ERW-HFW(HFW), API5L X52, 12 Mil Min FBE Coated Pipe hydrotested to 1300 +/- 25 psig - 2016 Pipeline Remediation (SAP #27544759, Mitch Loomis)

Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. SWML Manufacturing anomaly removed. SEAM WELD ML MANUFACTURING ANOMALY



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear Anomaly A and adjacent linear longitudinal weld anomalies removed. Linear anomaly A



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear Anomaly A removed. Linear anomaly A



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear Anomaly B's removed. Linear anomaly B


Removed and installed 51.95' of 20" x 0.344", ERW-HFW(HFW), API5L X52, 12 Mil Min FBE Coated Pipe hydrotested to 1300 +/- 25 psig - 2016 Pipeline Remediation (SAP #27544803, Mitch Loomis) Existing pipe was Pre-70's EFW. Removed existing joint to

eliminate seam threat since the joint was excavated and exposed. DEFORMATION ANOMALY-DENT

U-18424







Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Linear Anomaly B and Seam Weld ML Manufacturing Anomaly removed. Linear anomaly B



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Longitudinal weld anomaly and Seam Weld ML Manufacturing anomaly removed. Longitudinal weld anomaly



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Attachments and dent removed. Attachment / Dent



eliminate seam threat since the joint was excavated and exposed. EXTERNAL CLUSTER



Existing pipe was Pre-70's EFW. Removed existing joint to eliminate seam threat since the joint was excavated and exposed. Longitudinal weld anomaly, seam weld dent and extra metal removed. Longitudinal weld anomaly / Seam Weld Dent



eliminate seam threat since the joint was excavated and exposed. Linear anomaly B

1003.71

GL-01616 GL-01613 KZO-1200B Moscow Rd to Chelsea Double Submerged

26599409 KZO-1200B Moscow Rd to Chelsea C-REM General

28374360 KZO-1200B Moscow Rd to Chelsea C-REM Dig #1 Capital No Jackson Hanover 56.88

Removed and installed 56.88' of 36” x 0.532”, DSAW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #28374360, Peter Pryson) Linear Anomaly B removed EMAT: Linear anomaly B

28374361 KZO-1200B Moscow Rd to Chelsea C-REM Dig #2 Capital No Jackson Liberty 55.3

Removed and installed 55.3' of 36” x 0.532”, DSAW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #28374361, Peter Pryson) Linear Anomaly B removed EMAT: Linear anomaly B

28374362 KZO-1200B Moscow Rd to Chelsea C-REM Dig #3 Capital No Jackson Napoleon 51.07

Removed and installed 51.07' of 36” x 0.532”, DSAW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #28374362, Peter Pryson) ML Manufacturing anomaly removed ML MANUFACTURING ANOMALY

28665186 28374363 KZO-1200B Moscow Rd to Chelsea C-REM Dig #4 O&M No Jackson Grass lakeVerification

Only Verification Dig, No Pipe Cut out SEAM WELD ML MANUFACTURING ANOMALY

29005166 28374366 KZO-1200B Moscow Rd to Chelsea C-REM Dig #5 O&M No Washtenaw SylvanVerification

Only Verification Dig, No Pipe Cut out EXTRA METAL near seam weld

28374367 KZO-1200B Moscow Rd to Chelsea C-REM Dig #6 Capital No Washtenaw Sylvan 55.33

Removed and installed 55.33' of 36” x 0.532”, DSAW, API5L-X65, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #28374367, Peter Pryson) External cluster corrosion removed EXTERNAL CLUSTER

28374369 KZO-1200B Moscow Rd to Chelsea C-REM Dig #7 Capital No Washtenaw SylvanVerification

Only Verification Dig, removed and replaced 50 sq ft of coating Over 50 sq. ft of new coating was installed. ML MANUFACTURING ANOMALY

218.58

GL-01617 GL-01620 FDM-2800 Freedom to Clawson Seamless & DSAW

26591528 FDM-2800 Freedom to Clawson O-REM General

26599410 FDM-2800 Freedom to Clawson C-REM General

27857633 FDM-2800 Freedom to Clawson C-REM Dig #1 Capital No Washtenaw Freedom 59.46

Removed and installed 59.46' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857633, Kathryn Maloney)

Dent with a field bend removed along with Ext ML Corrosion upstream of the field bend joint.

DEFORMATION ANOMALY-DENT associated with field bend

27857680 FDM-2800 Freedom to Clawson C-REM Dig #2 DeferredDeferr

ed Deferred Deferred Deferred INTERNAL CLUSTER



Linear Anomaly A and ML Manufacturing, cut-out entire joint of pipe Linear anomaly A


ed Deferred Deferred Deferred EXTERNAL CLUSTER



Multiple Linear Anomaly B Indications along with corrosion spread out over multiple joints of pipe. EXTERNAL ML CORROSION / Linear anomaly B



Linear Anomaly B, Corrosion and an attachment spread out over multiple joints of pipe. Linear anomaly B with corrosion

27857754 FDM-2800 Freedom to Clawson C-REM Dig #7 Capital No Washtenaw Freedom 51

Removed and installed 51' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857754, Kathryn Maloney) Puddle weld - entire joint of pipe was removed.

EXTRA METAL possible puddle weld (called dent with extra metal in ROSEN 2012 survey)

U-18424





28181390 27857803 FDM-2800 Freedom to Clawson C-REM Dig #8 O&M No Washtenaw Scio 9

Removed and installed 9' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #28181390, Kathryn Maloney) DEFORMATION ANOMALY-DENT


ed Deferred Deferred Deferred EXTERNAL ML CORROSION

27857819 FDM-2800 Freedom to Clawson C-REM Dig #10 Capital No Washtenaw Scio 75.9

Removed and installed 75.9' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857819, Kathryn Maloney) Corrosion removed over multiple joints of pipe EXTERNAL CLUSTER


ed Deferred Deferred Deferred EXTRA METAL


Removed and installed 54.62' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857857, Kathryn Maloney) Extra Metal at a field bend, entire joint removed EXTRA METAL associated with field bend


Removed and installed 51.1' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857866, Kathryn Maloney) Linear Anomaly B, entire joint removed Linear anomaly B / N/A / with corrosion


Removed and installed 193.3' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857875, Kathryn Maloney) Dent removed along with corrosion DEFORMATION ANOMALY-DENT


Removed and installed 56.61' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857904, Kathryn Maloney) Dent removed, with a bend installed, additional pipe needed DEFORMATION ANOMALY-DENT


ed Deferred Deferred Deferred DEFORMATION ANOMALY-DENT

27857919 FDM-2800 Freedom to Clawson C-REM Dig #17 Deferred No Washtenaw Northfield Deferred EXTERNAL ML CORROSION

27857920 FDM-2800 Freedom to Clawson C-REM Dig #18 Deferred No Washtenaw Northfield Deferred EXTERNAL ML CORROSION

27857921 FDM-2800 Freedom to Clawson C-REM Dig #19 Capital No Washtenaw Northfield 52.66

Removed and installed 59.46' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857922, Kathryn Maloney) Corrosion removed, entire joint taken EXTERNAL CLUSTER




Removed and installed 51.2' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857923, Kathryn Maloney) Linear Anomaly B, entire joint removed Group of linear anomalies B / N/A / with corrosion


Removed and installed 55.35' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857924, Kathryn Maloney) Dent and External corrosion removed

DENT DETECTED W/METAL LOSS associated with field bend





27857927 FDM-2800 Freedom to Clawson C-REM Dig #25 Capital Yes Oakland Lyon 158.61

Removed and installed 158.61' of 18” x 0.318”, ERW-HFW, API5L-X52, FBE Coated Pipe hydrotested to 1500 +/- 25 psig - 2016 Pipeline Remediation (SAP #27857927, Kathryn Maloney) Multiple joints of internal corrosion removed INTERNAL CLUSTER

1216.1

- 1 -

Michigan Public Service Commission MPSC Staff: Cindy Creisher. Operations & Wholesale Markets Division Audit Request: CLC-12 Consumers Gas Rate Case: U-18424 Date of Request: 01/23/2018

1. In regards to “Attachment 11, Filing Requirement #6”, please provide the associated in-line inspection (Pipe Listing) reports received from the vendors for each of the pipelinescovered in the “2016 Remediation Dig Summary” that was submitted. This report is toinclude the entire listing of every feature identified during the inspection, in spreadsheetformat, as was provided to Consumers directly from the in-line inspection vendor.Additionally, please update the “2016 Remediation Dig Summary” with the featureidentification numbers that correspond with those in the report received from the vendor.

2. Please provide the same information as provided in response to Audit Request Question 1of CLC-12 for the 2017 Remediation Dig Summary when it is available.

Welding Procedure Specification 1 GCD 42

Consumers Energy February 2014 WPS

Supporting PQRs: SMHV-4222E, SMHB-4222A Qualified to: API 1104 20th ED

Welding Processes Welding Process: Shield Metal Arc Welding

Method of Application: Manual

Power Supply: Constant Current

Polarity: Direct Current Electrode Positive (DCEP)

Pipe and Fittings Materials Pipe and Fitting Materials: API 5L Specification Grade X42 and less Yield Strength

materials and conforming ASTM materials.

Branch connections: API 5L Specification Grade X42 and less Yield Strength materials and conforming ASTM materials.

Diameter Range: Pipe and Fittings: Unlimited Branch Connection: 12.750″ O.D. and less.

Wall Thickness Range: Pipe and Fittings: Unlimited Branch Connection: Unlimited

Filler Metal AWS Specification: A5.1 and A5.5

AWS Classification: E6010 and E7010

Electrode Diameter: 3/32″, 1/8″, 5/32″, or 3/16″

Positions

Work Positions: All fixed positions.

Progression: When weld axis is vertical progression shall be downhill.

Preheat Preheat Requirements: Required when ambient or material temperature is below 40°F

or when moisture is present on or near the weld joint. Required when wall thickness of pipe or fitting exceeds 0.500″.

Temperature: 250°F minimum temperature. Maintain minimum temperature until weld is complete. Measure 3-4″ away from each side of weld joint.

Inter-pass Temperature: 500°F maximum temperature. Measure approximately 1″ from each side of weld joint edge.

Methods: Thermal torch or induction heating.

Post Heat Treatment: None.

2 GCD 42 Welding Procedure Specification

WPS February 2014 Consumers Energy

Time Lapse Between Passes • Time lapse between root and first fill pass (hot pass) shall not exceed 5 minutes. • Time lapse between remaining passes should not exceed 10 minutes. If 10 minutes has

been exceeded, preheat and maintain temperature of welding joint to 250°F before applying additional weld passes.

Cleaning • Clean welding surface of all rust, scale, primer, oil, or other material that may be

detrimental to the finished weld.

• Remove all non-metallic residue on every weld pass prior to depositing any additional weld passes.

• Manual or power tools may be used (files, brushes, grinders).

• Grind all stops and starts of root pass and tack welds.

Clamping

• No clamping is required for installation of sleeves, branch fittings or other pipeline appurtenances.

• Prefabricated assemblies may use tack welds for preserving alignment.

• Welded joints utilizing internal clamps shall have the root pass completed before removal of clamping devise is permitted.

• Welded joints utilizing external clamps for the purpose of preserving alignment shall have the following root segments completed before removing clamping devise:

Nominal Pipe Diameter (inches)

Percentage of Root Pass Completed

2 to < 4 15%

4 to < 6 25%

6 to < 8 35%

8 to < 12 40%

12 and Greater 50%

*Root pass segments shall be equally spaced around circumference before releasing clamp.

Welding Procedure GCD 42 3 Specification


Welding Variables

All Weld Types (Single V Groove, Branch, Fillet)

Wall Thickness (inches) Weld Pass

Electrode

Classification¹

Electrode Diameter3

(inch) Volts Amps

Travel Speed² (inches per

minute)

All Root E6010 E6010 E6010

3/32″, 1/8″ or 5/32”

22-32 22-32 22-32

50-85 80-125 100-165

6-18 6-18 6-18

All First Fill / Hot Pass

E7010 E7010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

6-18 6-18

All Fill/Cap E7010 E7010 E7010

1/8″, 5/32″ or 3/16″4

22-32 22-32 22-32

80-125 100-165 140-210

6-18 6-18 6-18

1. Root passes deposited with E6010 electrodes, Fill and Cover passes deposited with either E6010 or E7010 electrodes. 2. Stringer or Weave passes are acceptable when applied within these ranges. Travel Speed is measured in the direction of welding progression. Weave motion perpendicular to the direction of travel is not included in the travel speed measurement. 3. If Electrode diameter 3/16″ is used for the fill and cap on V-Groove joints, the minimum number of passes can be reduced by 1. This applies only to V-Groove joints. See V-Groove Weld Sequence and Minimum Number of passes below. 4. The 3/16″ Electrode Diameter can only be used on pipe with wall thickness greater than 0.250″



Wall Thickness

Min. # Passes

< 0.188 2

< 0.250 4

< 0.375 4

< 0.500 6

< 0.625 9

> 0.625 12

Wall Thickness

Min. # Passes

< 0.188 2

< 0.250 3

< 0.375 4

< 0.500 5

< 0.625 7

> 0.625 10

Joint Designs

Lap Joint (Socket Weld)

• RO: Root Opening: 0 to 1/8″ • IG: Insertion Gap: 1/16″ min.

Single Bevel (Branch Weld)

• Root Opening: 3/32″ to 3/16″ • Root Face: 1/16″ to 3/32″ • Angle: 45° min. in crotch

Single V Groove (Butt Weld)

• Root Opening: 1/16″ to 3/16″ • Root Face: 1/16″ to 3/32″ • Groove Angle: 60° to 75°

(bevel angle: 30° to 37.5°)

IG

Single – V Groove Weld Sequence & Minimum Number of Passes

Horizontal Pipe

RO

Vertical/Inclined Pipe



Weld Sequence and Minimum Number of Passes

Acceptable/Unacceptable Fillet Weld Profiles

Lap Joints (Socket Welds) Single Bevel (Branch Welds)

Lap Joint-Fillet weld

Wall Thickness

Min. Number Passes

< 0.188 2 < 0.250 2 < 0.375 4 < 0.500 4 < 0.625 6 > 0.625 9

Single Bevel – Branch Weld

Wall Thickness

Min. Number Passes

< 0.188 2 < 0.250 4 < 0.375 4 < 0.500 7 < 0.625 7 > 0.625 10

Fillet Weld Size

T1 = Branch/Socket/Sleeve

T2 = Pipe Wall Thickness

L1 = Leg Length (Size)

L2 = Leg Length of Fillet Reinforcement

• L1 = T1 or T2 whichever is thinner but not less than 1/4″ (plus Root Opening)

• L2 = 1/4″ min., no greater than 0.5 x T2

T2

T2

T1

T1

L1

L2

Welding Procedure Specification GCD 60

Supporting PQRs: SMHB-6022b, SMHV-6032, SMHV-6032b & SMHB-6022c Qualified to: API 1104 20th ED





Pipe and Fittings Materials Pipe and Fitting Materials: API 5L Specifications greater than Grade X42 up to/including

X60 pipe and conforming ASTM materials.

Branch connections: API 5L Specifications greater than Grade X42 up to/including X60 pipe and conforming ASTM materials.

Diameter Range: Pipe and Fittings: Unlimited

Branch Connection: 12.750 inch O.D. and less.

Wall Thickness Range: Pipe and Fittings: Unlimited

Branch Connection: Unlimited


AWS Classification: E6010 for root passes; all grades

E7010 for first fill, hot pass and cap; all grades

E8010 for first fill, hot pass and cap; Grades X56 and X60 only

Electrode Diameter: 1/8”, 5/32”, 3/16”

Positions

Work Positions: All fixed positions.


Preheat Preheat Requirements: Required when ambient or material temperature is below 40° F

or when moisture is present on or near the weld joint. Required when wall thickness of pipe or fitting exceeds .500 inch. Required when branch connection exceeds 2 inches in diameter.

Temperature: 300o F on branch joints and 250° F minimum temperature on all other joints. Maintain minimum temperature until weld is

Consumers Energy May 2014 WPS

Welding Procedure GCD 60 Specification

complete. Measure three to four inches away from each side of weld joint.

Inter-pass Temperature: 500°F maximum temperature. Measure approximately one inch from each side of weld joint edge.


Post Heat Treatment: None.

Time Lapse Between Passes • Time lapse between root and first fill pass (hot pass) shall not exceed 5 minutes. • Time lapse between remaining passes should not exceed 10 minutes. If 10 minutes has

been exceeded, preheat and maintain temperature of welding joint to 250° F before applying additional weld passes.




• Manual or Power tools may be used (files, brushes, grinders).


Clamping







2 to < 4 15%

4 to < 6 25%

6 to < 8 35%

8 to < 12 40%

12 and Greater 50%


WPS May 2014 Consumers Energy


Welding Variables



Electrode

Classification¹

Electrode Diameter3

(inch) Volts Amps

Travel Speed² (inches per

minute)

All Root E6010 E6010

1/8” or 5/32”

22-32 22-32

80-125 100-165

6-12 6-12

All

First Fill / Hot Pass


E7010 E7010

E80101

E80101

1/8 “ or 5/32”

1/8” or 5/32”

22-32 22-32

22-32 22-32

80-125 100-165

75-130 90-185

4-10 4-10

4-10 4-10

All

Fill/Cap

Fill/Cap

E7010 E7010 E7010

E80101

E80101

E80101

1/8”, 5/32” or 3/16”4

1/8” 5/32” or 3/16”4

22-32 22-32 22-32

22-32 22-32 22-32

80-125 100-165 140-210

75-130 90-185 140-225

4-12 4-12 4-12

4-12 4-12 4-12

1. Root passes deposited with E6010 electrodes, Fill and Cover passes deposited with E7010 electrodes, E8010 Electrodes are optional on pipe grades X56 and X60. 2. Stringer or Weave passes are acceptable when applied within these ranges. Travel Speed is measured in the direction of welding progression. Weave motion perpendicular to the direction of travel is not included in the travel speed measurement. 3. If Electrode diameter 3/16” is used for the fill and cap on V-Groove joints, the minimum number of passes can be reduced by 1. This applies only to V-Groove joints. See V-Groove Weld Sequence and Minimum Number of passes below. 4. The 3/16” Electrode Diameter can only be used on pipe with wall thickness greater than 0.250”



Wall Thickness

Min. # Passes

< .188 2

< .250 4

< .375 4

< .500 6

< .625 9

> .625 12

Wall Thickness

Min. # Passes

< .188 2

< .250 3

< .375 4

< .500 5

< .625 7

> .625 10

Joint Designs








IG


Horizontal Pipe

RO


WPS May 2014 Consumers Energy






Wall Thickness

Min. Number Passes

< .188 2 < .250 2 < .375 4 < .500 4 < .625 6 > .625 9


Wall Thickness

Min. Number Passes

< .188 2 < .250 4 < .375 4 < .500 7 < .625 7 > .625 10

Fillet Weld Size







T2

T2

T1

T1

L1

L2




Supporting PQRs: SMHV-6532D, SMHB-6522A Qualified to: API 1104 20th ED





Pipe and Fittings Materials Pipe and Fitting Materials: API 5L Specification Grade X65 and conforming ASTM

materials.

Branch connections: API 5L Specification Grade X65 and conforming ASTM materials.





Electrode Diameter: 1/8″, 5/32″, 3/16″

Maximum Bead Thickness: 1/8″ maximum thickness deposit per pass

Positions

Work Positions: All fixed positions


Preheat Preheat Requirements: Preheat is necessary in all conditions.




Measurement: Temperature indicating crayons, pyrometer or thermal-couple. 1-3″ both sides from weld joint.

Post Heat Treatment: Not required.



Time Lapse Between Passes • Time lapse between root and first fill pass (hot pass) shall not exceed 5 minutes • Time lapse between remaining passes should not exceed 10 minutes. If 10 minutes has







Clamping







2 to < 4 15%

4 to < 6 25%

6 to < 8 35%

8 to < 12 40%

12 and Greater 50%




Welding Variables



Electrode

Classification¹ Electrode Diameter3

(inch) Volts Amps

Travel Speed²

(inches per minute)

Less than 0.250 Root E6010 1/8″ 22-32 80-125 5-15

Less than 0.250


E8010 E8010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

5-15

Less than 0.250 Fill/Cap

E8010 E8010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

4-14

Greater than 0.250 Root

E6010 E6010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

5-15

Greater than 0.250


E8010 E8010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

5-15

Greater than 0.250 Fill/Cap

E8010 E8010

5/32″ or 3/16″

22-32 22-32

100-165 140-210

4-14

1. Root passes deposited with E6010 electrodes, Fill and Cover passes deposited with E8010 electrodes. 2. Stringer or Weave passes are acceptable when applied within these ranges. Travel Speed is measured in the direction of welding progression. Weave motion perpendicular to the direction of travel is not included in the travel speed measurement. 3. If Electrode diameter 3/16″ is used for the fill and cap on V-Groove joints, the minimum number of passes can be reduced by 1. This applies only to V-Groove joints. See V-Groove Weld Sequence and Minimum Number of passes below.



Wall Thickness

Min. # Passes

< 0.188 2

< 0.250 4

< 0.375 4

< 0.500 6

< 0.625 9

> 0.625 12

Wall Thickness

Min. # Passes

< 0.188 2

< 0.250 3

< 0.375 4

< 0.500 5

< 0.625 7

> 0.625 10

Joint Designs








IG


Horizontal Pipe

RO








Wall Thickness

Min. Number Passes

< 0.188 2 < 0.250 2 < 0.375 4 < 0.500 4 < 0.625 6 > 0.625 9


Wall Thickness

Min. Number Passes

< 0.188 2 < 0.250 4 < 0.375 4 < 0.500 7 < 0.625 7 > 0.625 10

Fillet Weld Size







T2

T2

T1

T1

L1

L2



Supporting PQRs: SMHV-7032B, SMHB-7022A Qualified to: API 1104 20th ED





Pipe and Fittings Materials Pipe and Fitting Materials: API 5L Specification Grade X70 and conforming ASTM

materials.

Branch connections: API 5L Specification Grade X70 and conforming ASTM materials.





Electrode Diameter: 1/8″, 5/32″, 3/16″

Maximum Bead Thickness: 1/8″ maximum thickness deposit per pass

Positions

Work Positions: All fixed positions


Preheat Preheat Requirements: Preheat is necessary in all conditions.




Measurement: Temperature indicating crayons, pyrometer or thermal-couple. 1-3″ both sides from weld joint.

Post Heat Treatment: Not required.



Time Lapse Between Passes • Time lapse between root and first fill pass (hot pass) shall not exceed 5 minutes • Time lapse between remaining passes should not exceed 10 minutes. If 10 minutes has







Clamping







2 to < 4 15%

4 to < 6 25%

6 to < 8 35%

8 to < 12 40%

12 and Greater 50%




Welding Variables



Electrode

Classification¹ Electrode Diameter3

(inch) Volts Amps

Travel Speed²

(inches per minute)

Less than 0.250 Root E6010 1/8″ 22-32 80-125 5-15

Less than 0.250


E8010 E8010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

5-15

Less than 0.250 Fill/Cap

E8010 E8010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

4-12

Greater than 0.250 Root

E6010 E6010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

5-15

Greater than 0.250


E8010 E8010

1/8″ or 5/32″

22-32 22-32

80-125 100-165

5-15

Greater than 0.250 Fill/Cap

E8010 E8010

5/32″ or 3/16″

22-32 22-38

100-165 140-210

4-12

1. Root passes deposited with E6010 electrodes, Fill and Cover passes deposited with E8010 electrodes. 2. Stringer or Weave passes are acceptable when applied within these ranges. Travel Speed is measured in the direction of welding progression. Weave motion perpendicular to the direction of travel is not included in the travel speed measurement. 3. If Electrode diameter 3/16″ is used for the fill and cap on V-Groove joints, the minimum number of passes can be reduced by 1. This applies only to V-Groove joints. See V-Groove Weld Sequence and Minimum Number of passes below.



Wall Thickness

Min. # Passes

< 0.188 2

< 0.250 4

< 0.375 4

< 0.500 6

< 0.625 9

> 0.625 12

Wall Thickness

Min. # Passes

< 0.188 2

< 0.250 3

< 0.375 4

< 0.500 5

< 0.625 7

> 0.625 10

Joint Designs








IG


Horizontal Pipe

RO








Wall Thickness

Min. Number Passes

< 0.188 2 < 0.250 2 < 0.375 4 < 0.500 4 < 0.625 6 > 0.625 9


Wall Thickness

Min. Number Passes

< 0.188 2 < 0.250 4 < 0.375 4 < 0.500 7 < 0.625 7 > 0.625 10

Fillet Weld Size







T2

T2

T1

T1

L1

L2

Dig Old New ∆ Old New ∆2 40.61 58 17.39 04 38.18 9.03 ‐29.15 09 41.53 63.8 22.27 011 27.11 9 ‐18.11 0

42.158.1

17 44.13 12.98 ‐31.15 018 24.34 67.79 43.45 020 45.03 0 ‐45.03 023 40.33 50.65 10.32 024 43.65 51.95 8.3 0

Dig Old New ∆ Old New ∆8 20.08 32.56 12.48 09 20.1 55.1 35 010 19.94 31.66 11.72 013 19.51 0 ‐19.51 014 19.06 81.84 62.78 015 20.21 0 ‐20.21 020 20.32 62.33 42.01 021 20.07 51.85 31.78 023 20.31 50.87 30.56 024 20.31 65.62 45.31 0

Dig Old New ∆ Old New ∆3 40.71 0 ‐40.71 06 40.73 0 ‐40.73 0

16 45.28

Existing < 50'

04.97

Existing < 50'

Existing < 50'

L2800 ‐ Freedom to Clawson

L400 ‐ Laingsburg to Fenton

L2070 ‐ Dutton to Coolidge

Existing > 50'

Existing > 50'

Existing > 50'

Dig Old New ∆ Old New ∆1 51.2 51.982 62.78 64.173 41.31 21.31 ‐20 04 61.98 67.955 50.83 50.996 61.53 63.367 62.53 08 62.07 65.169 61.51 010 62.3 011 62.15 63.81

Existing < 50'

L2600 ‐ MAR‐Processing Plant to Gillow L/R

Existing > 50'

Dig Old New ∆ Old New ∆1 40.01 51.11 11.1 02 39.84 93.15 53.31 03 39.95 0 ‐39.95 04 39.91 122.58 82.67 05 39.78 60.28 20.5 06 39.91 51.86 11.95 07 39.97 52.14 12.17 08 40.03 75.36 35.33 09 40.01 52.38 12.37 010 39.98 52.02 12.04 011 39.11 51 11.89 012 39.99 50.82 10.83 013 23.93 65.6 41.67 014 39.97 52.97 13 015 40.06 50.78 10.72 016 39.61 52 12.39 017 40.08 50.73 10.65 018 38.22 50.15 11.93 019 39.95 0 ‐39.95 020 40.01 81.07 41.06 021 40.04 135.95 95.91 022 40.09 51.99 11.9 023 0 024 40.04 51.61 11.57 025 40.06 51.89 11.83 026 40 50.99 10.99 027 40.15 81.23 41.08 028 39.97 0 ‐39.97 029 40.06 81.83 41.77 030 39.98 53.97 13.99 031 38.09 50.85 12.76 032 33.89 54.8 20.91 033 40.03 0 ‐40.03 034 39.85 79.37 39.52 035 40.01 0 ‐40.01 0E1 40.03 52.16 12.13 0E2 39.98 52.07 12.09 0E3 39.84 50.79 10.95 0E4 40.01 50.84 10.83 0E5 40.05 50.83 10.78 0E6 39.94 51.07 11.13 0

Existing < 50'

L1200A ‐ KZO‐White Pigeon to V Drive South

Existing > 50'

Dig Old New ∆ Old New ∆1 0 64.86 0 ‐64.862 0 60.59 0 ‐60.593 0 64.94 0 ‐64.944 0 05 20.02 0 ‐20.02 0

Dig Old New ∆ Old New ∆1 11.74 0 ‐11.74 02 38.77 0 ‐38.77 03 40.92 0 ‐40.92 04 40.47 0 ‐40.47 05 40.95 0 ‐40.95 06 40.72 0 ‐40.72 07 40.57 0 ‐40.57 08 40.81 0 ‐40.81 09 40.54 0 ‐40.54 010 40.42 0 ‐40.42 011 40.67 0 ‐40.67 012 21.76 23.85 2.09 0

Dig Old New ∆ Old New ∆1 43.56 0 ‐43.56 02 0 64.08 0 ‐64.083 2.63 9.05 6.42 04 0 57.79 57.84 0.05

L3200 ‐ FDM‐Vector Leslie to Kinder Morgan

L2200 ‐ FDM‐Chelsea to Fenton

L2020 ‐ NVL‐Pontiac to Decker

Existing < 50'

Existing < 50'

Existing < 50' Existing > 50'

Existing > 50'

Existing > 50'

Dig Old New ∆ Old New ∆1 48.1 52.1 4 02 41.59 50.5 8.91 03 47.88 51.1 3.22 04 47.29 51.1 3.81 05 47.56 51.3 3.74 06 47.4 74.2 26.8 0

Dig Old New ∆ Old New ∆1 37.96 50.91 12.95 02 40 50.86 10.86 03 40.08 0 ‐40.08 04 39.95 50.83 10.88 05 6.74 8.7 1.96 06 3.97 12.77 8.8 07 40.02 50.74 10.72 08 40.02 117.96 77.94 09 40.15 143.38 103.23 010 39.91 0 ‐39.91 011 36.92 50.72 13.8 012 39.93 51.31 11.38 0

Dig Old New ∆ Old New ∆1 5.16 60.1 54.94 02 39.84 50.34 10.5 03 39.54 0 ‐39.54 04 39.86 0 ‐39.86 05 39.87 51.23 11.36 06 0 77.02 0 ‐77.027 39.75 0 ‐39.75 08 39.82 0 ‐39.82 09 21.95 10 ‐11.95 0

L3010 ‐ KZO‐Olmstead to Galesburg

L1100 ‐ KZO‐Dorr to Middleville Caledonia

L100B ‐ SAG‐Herrick to MuskegonExisting < 50'

Existing < 50'

Existing < 50'

Existing > 50'

Existing > 50'

Existing > 50'

Dig Old New ∆ Old New ∆1 0 02 0 03 39.87 51.96 12.09 04 39.8 50.56 10.76 05 39.89 51.45 11.56 0

Dig Old New ∆ Old New ∆1 36.93 51.16 14.23 02 0 52.16 53.05 0.893 0 50.41 50.57 0.164 0 05 0 06 0 07 0 0

Existing > 50'

Existing < 50'

Existing < 50'

Existing > 50'STC‐Ira Mainline 20"

L600 ‐ STC‐Clarkston to Squirrel

Dig Old New ∆ Old New ∆1 47.17 54.84 7.67 02 46.49 51.5 5.01 03 44.65 68.5 23.85 04 35.63 50.47 14.84 05 46.79 51.69 4.9 06 40.83 50.24 9.41 07 47.17 8.89 ‐38.28 08 46.69 52.49 5.8 09 44.14 60.02 15.88 010 42.8 51.53 8.73 011 41.85 52.07 10.22 012 43.63 50.46 6.83 013 46.04 50.89 4.85 014 47.41 51.27 3.86 015 46.14 58.78 12.64 016 44.61 50.46 5.85 017 45.99 50.91 4.92 018 46.67 54.93 8.26 019 47.78 51.75 3.97 020 37.18 0 ‐37.18 021 47.61 51.47 3.86 022 48.3 51 2.7 023 44.83 57.64 12.81 024 44.67 51.52 6.85 025 43.84 52.2 8.36 026 47.57 50.48 2.91 027 43.02 55.78 12.76 028 42.25 51.25 9 0

46.5546.39

30 46.49 53.32 6.83 031 46.78 0 ‐46.78 0

47.839.27

54.54

96.632

29 ‐38.4

9.53

0

0

Existing > 50'Existing < 50'L1600 ‐ NVL‐Northville to Coolidge

Dig Old New ∆ Old New ∆1 0 60.18 61.59 1.412 0 59.99 118.44 58.453 0 53.78 54.8 1.024 0 60.52 0 ‐60.525 0 52.53 53.55 1.026 0 54.38 55.6 1.227 0 60.22 61.33 1.118 0 61.62 62.38 0.769 0 61.06 51.36 ‐9.710 0 60.85 62.02 1.1711 0 59.14 93.38 34.2412 0 60.28 60.92 0.64

21.4618.6259.82

15 49.63 86.63 37 016 29.8 0 ‐29.8 0

Dig Old New ∆ Old New ∆1 46.72 0 ‐46.72 02 47.3 51.52 4.22 03 45.64 55.29 9.65 04 46.15 50.25 4.1 05 46.2 13.06 ‐33.14 06 45.67 100.34 54.67 07 45.08 10 ‐35.08 0

13 60.62 61.70

‐49.6250.28

1.08

0

Existing > 50'Existing < 50'L1060 ‐ STC‐St. Clair to Mt. Clemens

L1020 ‐ NVL‐South Lyon to Northville Existing < 50' Existing > 50'

14

Dig Old New ∆ Old New ∆1 47.38 51.15 3.77 02 0 50.34 70.89 20.553 38.59 56.6 18.01 04 47.12 180.01 132.89 05 49.61 59.09 9.48 06 48.98 64.5 15.52 0

49.2849.949.6

8 48.6 58.33 9.73 09 49.32 51.34 2.02 010 0 51.13 57.11 5.9811 0 50.35 56.89 6.5412 41.87 53.5 11.63 013 49.28 56.35 7.07 014 49.77 0 ‐49.77 015 49.2 57.7 8.5 016 0 017 45.02 58.18 13.16 018 48.2 0 ‐48.2 019 45.87 57.18 11.31 020 29.7 57.84 28.14 0M22 13.08 12.09 ‐0.99 0M23 29.55 56.21 26.66 0M24 18.3 67.12 48.82 0

Dig Old New ∆ Old New ∆1 0 63.45 65.28 1.832 0 79.33 81.48 2.153 0 55.7 58.07 2.374 0 78.02 79.93 1.915 0 06 0 67.76 69.38 1.627 0 76.64 0 ‐76.648 0 71.44 78.26 6.829 0 59.69 30.5 ‐29.19

73.0862.32

11 0 58.82 0 ‐58.8212 0 66.2 68.55 2.35

010

52.83


0

L250 ‐ SAG‐Mt Pleasant to Zilwaukee

L1800 ‐ KZO‐Schoolcraft to Plainwell

0 ‐135.4


7 201.61

Dig Old New ∆ Old New ∆1 43.87 57.44 13.57 02 0 79.13 85.05 5.923 0 78.29 80.3 2.014 0 73.75 76.1 2.355 0 67.19 0 ‐67.196 0 76.9 82.78 5.887 48.72 1946.25 1897.53 08 0 79.7 95.92 16.229 0 78.31 0 ‐78.3110 0 66.54 69.62 3.0811 0 75.36 17.96 ‐57.412 0 70.17 72.33 2.16

14 0 65 67.15 2.1515 0 78.52 80.94 2.4216 0 77.69 79.89 2.217 0 74.9 77 2.118 0 71 73.13 2.1319 0 0

Dig Old New ∆ Old New ∆1 0 76.79 82.11 5.322 0 79.6 81.72 2.123 0 51.56 52.85 1.294 0 74.79 75.96 1.175 0 74.22 225.5 151.286 0 60.52 65.65 5.137 0 64.81 65.98 1.178 0 55.83 0 ‐55.839 0 67.08 68.88 1.810 0 74.88 76.65 1.7711 0 64.93 66.85 1.9212 0 52.77 0 ‐52.7713 0 79.85 0 ‐79.85

2.641.862.092.4915 43.2

14 29.62

13 73.27 75.44

25.12

38.62


0

0

L1800 ‐ KZO‐White Pigeon to Schoolcraft

L1800 ‐ KZO‐Plainwell to 30th


Dig Old New ∆ Old New ∆1 8.02 105.29 97.27 02 0 52.98 64.97 11.993 0 50.87 142.07 91.24 0 50.86 137.87 87.015 0 50.47 52.46 1.996 47.71 125.06 77.35 07 0 52.11 66.59 14.488 0 50.28 53.2 2.929 44.67 128.06 83.39 010 0 50.16 124.02 73.8611 0 51.12 168.37 117.2512 0 50.41 166.64 116.2313 0 50.48 210.88 160.414 48.43 268.07 219.64 015 45.81 83.29 37.48 016 35.69 56.22 20.53 017 0 50.34 104.22 53.8818 0 52.27 65.01 12.7419 0 52.04 208.4 156.3620 49.35 105.62 56.27 021 0 52.96 120.3 67.3422 46.84 56.05 9.21 023 48.14 301.84 253.7 024 49.7 186.38 136.68 025 48.9 169.54 120.64 026 48.74 201.45 152.71 0

27 46.18Not

Provided0 0

28 0 51.18 104.53 53.3529 0 52.39 65.37 12.9830 48.82 62.08 13.26 031 49.94 55.97 6.03 032 19.03 52.79 33.76 040 0 041 47.77 50.88 3.11 042 0 0E1 49.36 54.29 4.93 0E2 46.68 56.61 9.93 0E3 49.41 51.48 2.07 0E4 49.31 55.46 6.15 0E5 0 51.4 65.19 13.79E6 0 51.43 96.1 44.67

Existing < 50' Existing > 50'L100C ‐ SAG‐Airport to Herrick

Dig Old New ∆ Old New ∆1 35.06 0 ‐35.06 02 39.91 0 ‐39.91 03 30.99 0 ‐30.99 04 33.58 0 ‐33.58 05 41.45 0 ‐41.45 0

33.5930.13

7 38.07 52.23 14.16 08 29.4 54.99 25.59 09 13.73 19.93 6.2 0

Dig Old New ∆ Old New ∆1 0 60.84 73.46 12.622 0 59.93 34.44 ‐25.493 0 59.97 62 2.034 0 60.09 0 ‐60.095 0 59.83 0 ‐59.836 0 53.83 58.64 4.817 0 57.96 9.84 ‐48.128 0 59.98 62.33 2.359 0 59.64 62.38 2.7410 38.85 41.95 3.1 011 26.42 9.17 ‐17.25 012 29.99 65.63 35.64 013 34.9 39 4.1 0

Existing joints <50' with 5'+ extra replacement where replacements occur130 out of 154

Existing joints >50' with 5'+ extra replacement where replacements occur29 out of 69

6 120.3

L1080 ‐ FDM‐Maple Dale to Park Rd

56.58



0

L2500 ‐ M72 VS to Shell Processing Plant

Supplemental Response - Confidential Request #: 156 Page 1 of 1

MPSC AUDIT REQUEST

CASE NO: U-18424 DATE OF REQUEST: 01/23/2018 NO. CLC-12 REQUESTED BY: Cindy L. Creisher DATE OF RESPONSE: 2/27/2018 RESPONDENT: Mary P. Palkovich

Question:

2. Please provide the same information as provided in response to Audit Request Question 1 of CLC-12 for the 2017 Remediation Dig Summary when it is available.

Answer:

CONFIDENTIAL Please see the attached excel files which contain the information requested in this interrogatory.

2017 REMEDIATION DIG SUMMARY U‐18424 MPSC Staff Audit Rqst 156 Revised


Capital Dig HCA County Township Pup Size (ft) Description

Feature Identification

Number (ILI Item Number) Anomaly Type

GL‐01617 GL‐01620 L2800 ‐ Freedom to Clawson

29253045 L2800 ‐ Freedom to Clawson ‐ O&M General

29059668 L2800 ‐ Freedom to Clawson ‐ Capital General

27857680 L2800 ‐ Freedom to Clawson ‐ Dig #2 Capital No Washtenaw Freedom 58

Removed and installed 58' of 18” x 0.375”, ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #27857680, Kevin Fielder)

115 & 127INTERNAL CLUSTER

30217164 27857690 L2800 ‐ Freedom to Clawson ‐ Dig #4 O&M No Washtenaw Freedom 9.03

Removed and installed 9.03' of 18” x 0.375”, ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30217164, Kevin Fielder)

552EXTERNAL CLUSTER

27857811 L2800 ‐ Freedom to Clawson ‐ Dig #9 Capital No Washtenaw Scio 63.8


1313EXTERNAL ML CORROSION

30217165 27857848 L2800 ‐ Freedom to Clawson ‐ Dig #11 O&M No Washtenaw Scio 9

Removed and installed 9' of 18” x 0.375”, ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30217165, Kevin Fielder)

1610‐1614 EXTRA METAL


Removed and installed 42.15' of 18” x 0.375”, ERW, API5L‐X65, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP 27857914, Kevin Fielder)

2698 DEFORMATION ANOMALY‐DENT


Removed and installed 8.10' of 18” x 0.375”, ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP 27857914, Kevin Fielder)


30217166 27857919 L2800 ‐ Freedom to Clawson ‐ Dig #17 O&M No Washtenaw Northfield 12.98



27857920 L2800 ‐ Freedom to Clawson ‐ Dig #18 Capital No Washtenaw Northfield 67.79



27857922 L2800 ‐ Freedom to Clawson ‐ Dig #20 Capital No Washtenaw Northfield 0No Pipe Cut‐out. >50 Sq Ft Recoated. (SAP #27857922, Kevin Fielder)











415.77

GL‐01596 GL‐01595 L400 ‐ Laingsburg to Fenton

29253048 Line 400 ‐ Laingsburg to Fenton ‐ O&M General

29059670 Line 400 ‐ Laingsburg to Fenton ‐Capital General

30217160 29901394 Line 400 ‐ Laingsburg to Fenton ‐ Dig #8 O&M No Shiawassee Burns 32.56

Removed and installed 32.56' of 24” x 0.375”, ERW, API5L‐X65, FBE Coated Pipe hydrotested to 1475 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30217160, Mitch Loomis)

3809 EXTRA METAL Possible puddle weld, caliper indicates ID reduction < 1%

29901395 Line 400 ‐ Laingsburg to Fenton ‐ Dig #9 Capital No Shiawassee Burns 55.1


4158 EXTRA METAL Possible puddle weld

3/15/2018

30217161 29901396 Line 400 ‐ Laingsburg to Fenton ‐ Dig #10 O&M No Shiawassee Antrim 31.66



30217162 29901397 Line 400 ‐ Laingsburg to Fenton ‐ Dig #13 O&M No Shiawassee Antrim 0 Verification Dig, No pipe replaced (SAP #30217162, Mitch Loomis) 5845 Attachment

29901398 Line 400 ‐ Laingsburg to Fenton ‐ Dig #14 Capital No Shiawassee Antrim 81.84



30574146 29901399 Line 400 ‐ Laingsburg to Fenton ‐ Dig #15 O&M No Shiawassee Antrim 0 Verification Dig, No pipe replaced (SAP #30574146, Mitch Loomis) 6021 AM WELD ML MANUFACTURING ANOMA

29901580 Line 400 ‐ Laingsburg to Fenton ‐ Dig #20 Capital No Shiawassee Perry 62.33


8531AM WELD ML MANUFACTURING ANOMA

30217163 29901581 Line 400 ‐ Laingsburg to Fenton ‐ Dig #21 Capital No Shiawassee Perry 51.85



29901582 Line 400 ‐ Laingsburg to Fenton ‐ Dig #23 Capital No Shiawassee Sciota 50.87



29901584 Line 400 ‐ Laingsburg to Fenton ‐ Dig #24 Capital No Shiawassee Sciota 65.62



431.83

GL‐01603 GL‐01604 L2070 ‐ Dutton to Coolidge

29253049 L2070 ‐ Dutton to Coolidge ‐ O&M General

29253333 L2070 ‐ Dutton to Coolidge ‐ Capital General

28181801 L2070 ‐ Dutton to Coolidge ‐ Dig #3 Capital Yes Oakland Oakland 0No Pipe Removed. New coating installed in excess of 50 sq. ft. (SAP 28181801, Mitch Loomis) 1171 DEFORMATION ANOMALY‐DENT

28181804 L2070 ‐ Dutton to Coolidge ‐ Dig #6 Capital Yes Oakland Oakland 0No Pipe Removed. New coating installed in excess of 50 sq. ft. (SAP #28181804, Mitch Loomis)

2892‐2899,2901‐2907,2909‐2916 EXTRA METAL

0

GL‐01741 GL‐01766 L2600 ‐ MAR‐Processing Plant to Gillow L/R

29014840 L2600 ‐ MAR‐Processing Plant to Gillow‐ O&M General

29059671 L2600 ‐ MAR‐Processing Plant to Gillow‐ Capital Gen.

30977476 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #1 Capital No Kalkaska Orange 51.98

Removed and installed 51.98' of 12.75” x 0.375”, ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1900 +/‐ 25 psig ‐ 2017 Pipeline remediation (SAP #30977476, Mitch Loomis)




444XTERNAL ML CORROSION assoc. with seam

30977467 30977478 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #3 O&M No Kalkaska Orange 21.31


510 ML MANUFACTURING ANOMALY




30977480 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #5 Capital No Kalkaska Garfield 50.99


967XTERNAL ML CORROSION assoc. with seam

30977468 30977481 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #6 Capital No Kalkaska Garfield 63.36


1270 DEFORMATION ANOMALY‐DENT Associated with Field Bend

3/15/2018

30977469 30977482 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #7 Capital No Missaukee Pioneer 0No Pipe Removed. 53.41 sq. ft of new coating installed. (SAP #30977482, Mitch Loomis)

1780Attachment

30977470 30977483 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #8 Capital No Missaukee Norwich 65.16


2131 DEFORMATION ANOMALY‐DENT Associated with Field Bend

30977472 30977484 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #9 Capital No Missaukee Norwich 0No Pipe Removed. 56.75 sq. ft of new coating installed. (SAP #30977484, Mitch Loomis)


30977473 30977486 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #10 O&M No Missaukee Norwich 0No Pipe Removed. 13.35 sq. ft of new coating installed. (SAP #30977473, Mitch Loomis)

2366Extra Metal

30977474 30977488 L2600 ‐ MAR‐Processing Plant to Gillow‐ Dig #11 Capital No Missaukee Enterprise 63.81



448.73

GL‐01742 GL‐01767 L1200A ‐ KZO‐White Pigeon to V Drive South

29014848 L1200A ‐ KZO‐White Pigeon to V Drive South ‐ O&M

29059675 L1200A ‐ KZO‐White Pigeon to V Drive South ‐ Cap.

30855355 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #1 Capital No St Joseph White Pigeon 51.11

Removed and installed 51.11' of 26"” x 0.500”, SAWL, API5L‐X65, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline remediation (SAP #30855355, Pete Pryson)


30855356 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #2 Capital No St Joseph Sherman 93.15



30855358 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #3 Capital No St Joseph Sherman 0No Pipe Removed. 54.46 sq. ft of new coating installed. (SAP #30855358, Pete Pryson)


30855359 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #4 Capital No St Joseph Sherman 122.58


1378EXTERNAL SEAM WELD ML CORROSION

30855639 30855501 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #5 Capital No St Joseph Sherman 60.28


1802EXTERNAL CLUSTER

30855502 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #6 Capital No St Joseph Burr Oak 51.86


2288AM WELD ANOMALY ‐ A verified with EM

30855504 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #7 Capital No St Joseph Burr Oak 52.14



30855505 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #8 Capital No St Joseph Colon 75.36



30855507 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #9 Capital No St Joseph Colon 52.38



30855508 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #10 Capital No Branch Matteson 52.02



30855511 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #11 Capital No Branch Matteson 51

Removed and installed 51' of 26"” x 0.500”, SAWL, API5L‐X65, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline remediation (SAP #30855511, Pete Pryson)




4205AM WELD ANOMALY ‐ B verified with EM

3/15/2018




30855643 30855516 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #14 Capital No Branch Batavia 52.97



30855518 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #15 Capital No Branch Batavia 50.78



30855519 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #16 Capital No Branch Batavia 52

Removed and installed 52' of 26"” x 0.500”, SAWL, API5L‐X65, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline remediation (SAP #30855519, Pete Pryson)





30855523 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #18 Capital No Branch Batavia 50.15



30855646 30855526 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #19 O&M No Branch Batavia 0No Pipe Removed. No coating installed. (SAP #30855646, Pete Pryson)

5073 EXTRA METAL affecting seam weld




30855529 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #21 Capital No Branch Union 135.95



30855530 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #22 Capital No Branch Union 51.99


5533MATION ANOMALY‐DENT assoc. with girt

30855741 30855532 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #23 Cancelled No Branch Girard Cancelled Dig Cancelled5737

Attachment

30855533 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #24 Capital No Branch Girard 51.61



30855743 30855535 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #25 Capital No Branch Girard 51.89


5985MATION ANOMALY‐DENT assoc. with girt






6221RMATION ANOMALY‐DENT assoc. with fiel

30855744 30855540 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #28 Capital No Branch Girard 0No Pipe Removed. 61.27 sq. ft of new coating installed. (SAP #30855540, Pete Pryson)





30855543 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #30 Capital No Branch Butler 53.97



30855545 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #31 Capital No Branch Butler 50.85



3/15/2018

30855745 30855546 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #32 Capital No Calhoun Homer 54.8



30855747 30855548 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #33 O&M No Calhoun Homer 0No Pipe Removed. No coating installed. (SAP #30855747, Pete Pryson)

8520 EXTRA METAL

30855549 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #34 Capital No Calhoun Homer 79.37


8735EXTERNAL SEAM WELD CLUSTER

30855741 30855532 L1200A ‐ KZO‐White Pigeon to V Drive ‐ Dig #35 O&M No TBD TBD 0No Pipe Removed. 13.62 sq. ft of new coating installed. (SAP #30855741, Pete Pryson)

7687

31243268 L1200A ‐ KZO‐White Pigeon to V Drive ‐ EMAT #1 Capital No TBD TBD 52.16


3010E0004, 3010E0005, 3010E0006, 3010E0007

Linear anomalies



4580E0001, 4580E0003 Linear anomalies



16430E0002, 16430E0003, 16430E0004 Linear anomalies



17040E0002Linear anomalies







2168.24

GL‐01743 GL‐01768 L3200 ‐ FDM‐Vector Leslie to Kinder Morgan

29015176 L3200 ‐ FDM‐Vector Leslie to Kinder Morgan ‐ O&M

29059676 L3200 ‐ FDM‐Vector Leslie to Kinder Morgan ‐ Capital

31322611 31099255 L3200 ‐ FDM‐Vector Leslie to Kinder Morgan ‐ Dig #1 O&M No Jackson Rives 0Verification Dig, No pipe Cut‐out. Less than than 50 sq.ft of coating installed. (SAP #31322611, Mitch Loomis) 377 ML MANUFACTURING ANOMALY

31099256 L3200 ‐ FDM‐Vector Leslie to Kinder Morgan ‐ Dig #2 Capital No Jackson Rives 0

Verification Dig, No pipe Cut‐out. Clock‐Spring Repair completed over gouges that were buffed out. More than 50 sq.ft of coating installed. (SAP #31099256, Mitch Loomis)


31322612 31099257 L3200 ‐ FDM‐Vector Leslie to Kinder Morgan ‐ Dig #3 O&M No Jackson Blackman 0Verification Dig, No pipe Cut‐out. Less than than 50 sq.ft of coating installed. (SAP #31322612, Mitch Loomis) 809 FORMATION ANOMALY‐DENT near girth w

31099258 L3200 ‐ FDM‐Vector Leslie to Kinder Morgan ‐ Dig #4 Cancelled Cancelle Cancelled Cancelled Cancelled Cancelled 880 Cancelled

31322613 31099259 L3200 ‐ FDM‐Vector Leslie to Kinder Morgan ‐ Dig #5 O&M Yes Jackson Jackson ‐ City 0Verification Dig, No pipe Cut‐out. Less than than 50 sq.ft of coating installed. (SAP #31322613, Mitch Loomis) 1324 EXTRA METAL

0

GL‐01744 GL‐01769 L2200 ‐ FDM‐Chelsea to Fenton

29015321 L2200 ‐ FDM‐Chelsea to Fenton ‐ O&M General

29059677 L2200 ‐ FDM‐Chelsea to Fenton ‐ Capital General

30962581 30962387 L2200 ‐ FDM‐Chelsea to Fenton ‐ Dig #1 O&M No Washtenaw Sylvan 0

Pipeline remediation assessment, no Pipe Cut‐out. Investigated anomaly was on above grade launcher piping. Recoated with Sherwin Williams –Sher‐Tar ‐ 2017 Pipeline Remediation – Dig 1 (Superior order #29015321, SAP #30962581, Kevin Fielder)

10 ML MANUFACTURING ANOMALY near

seam weld

3/15/2018

30962388 L2200 ‐ FDM‐Chelsea to Fenton ‐ Dig #2 Capital No Washtenaw Sylvan 0

Pipeline remediation assessment, no Pipe Cut‐out. 8 feet of coating removed and 7 feet of coating removed. Both areas recoated with Trenton Wax ‐ 2017 Pipeline Remediation – Dig 2 (Superior order #29059677, SAP #30962388, Kevin Fielder)

57

INTERNAL ML CORROSION

30962582 30962389 L2200 ‐ FDM‐Chelsea to Fenton ‐ Dig #3 Capital No Washtenaw Lima 0

Pipeline remediation assessment, no Pipe Cut‐out. 6 feet of coating removed and recoated with Trenton Wax ‐ 2017 Pipeline Remediation – Dig 3 (Superior order #29059677, SAP #30962389, Kevin Fielder)

105

Attachment

30962390 L2200 ‐ FDM‐Chelsea to Fenton ‐ Dig #4 Capital No Washtenaw Lima 0


EMAT‐1 Manufacturing anomaly / for validation purposes only



EMAT‐2 Manufacturing anomaly / for validation purposes only



652 SEAM WELD ML MANUFACTURING

ANOMALY

30962583 30962394 L2200 ‐ FDM‐Chelsea to Fenton ‐ Dig #7 O&M No Washtenaw Lima 0


857

EXTRA METAL near seam weld

30962395 L2200 ‐ FDM‐Chelsea to Fenton ‐ Dig #8 Capital No Washtenaw Dexter 0

Pipeline remediation assessment, no Pipe Cut‐out. 6 feet of coating removed and recoated with Trenton Wax. Close metal object removed near 504+26 ‐ 2017 Pipeline Remediation – Dig 8 (Superior order #29059677, SAP #30962395, Kevin Fielder)


ANOMALY




ANOMALY



1824


30962398 L2200 ‐ FDM‐Chelsea to Fenton ‐ Dig #11 Capital No Livingston Oceola 0



ANOMALY

30962584 30962399 L2200 ‐ FDM‐Chelsea to Fenton ‐ Dig #12 O&M No Livingston Tyrone 23.85

X65, FBE Coated Pipe, pre‐construction hydrostatically tested to 1500 +/‐ 25 psig, Actual minimum test pressure 1478 psig ‐ 2017 Pipeline Remediation – Dig 12 (Superior order #29015321, SAP #30962584, Kevin Fielder)

5624 DEFORMATION ANOMALY‐DENT assoc.

with field bend

23.85

GL‐01745 GL‐01770 L2020 ‐ NVL‐Pontiac to Decker

29015323 L2020 ‐ NVL‐Pontiac to Decker ‐ O&M Gen.

29059678 L2020 ‐ NVL‐Pontiac to Decker ‐ Capital Gen.

31167144 30410053 L2020 ‐ NVL‐Pontiac to Decker ‐ Dig #1 O&M Yes Oakland Milford 0 Verification Dig, No pipe Cut‐out 108 EXTRA METAL

30410054 L2020 ‐ NVL‐Pontiac to Decker ‐ Dig #2 Capital No Oakland Commerce 0No Pipe Removed. New coating installed in excess of 50 sq.ft. (SAP #30410054, Walt Bies) 371 ML MANUFACTURING ANOMALY

30410058 30410055 L2020 ‐ NVL‐Pontiac to Decker ‐ Dig #3 O&M Yes Oakland Commerce 9.05

Removed and installed 9.05' of 20” x 0.375”, ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30410058, Walt Bies)

432‐434MAOP Verification Cut Out

3/15/2018

30410056 L2020 ‐ NVL‐Pontiac to Decker ‐ Dig #4 Capital Yes Oakland Commerce 57.84

Removed and installed 57.84' of 20” x 0.375”, ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30410056, Walt Bies)

623 SEAM WELD ML MANUFACTURING ANOMALY

66.89

GL‐01746 GL‐01771 L3010 ‐ KZO‐Olmstead to Galesburg

29015327 Line 3010 ‐Olmstead to Galesburg ‐ O&M

29059679 Line 3010 ‐Olmstead to Galesburg ‐ Capital

30855584 Line 3010 ‐Olmstead to Galesburg ‐ Dig #1 Capital Yes Kalamazoo Kalamazoo 52.1

Removed and installed 52.1' of 12.75” x 0.250”, HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1450 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30855584, Pete Pryson)

42INTERNAL ML CORROSION

30855585 Line 3010 ‐Olmstead to Galesburg ‐ Dig #2 Capital Yes Kalamazoo Kalamazoo 50.5



30855587 Line 3010 ‐Olmstead to Galesburg ‐ Dig #3 Capital No Kalamazoo Comstock 51.1












330.3

GL‐01747 GL‐01772 L1100 ‐ KZO‐Dorr to Middleville Caledonia

29015332 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ O&M

29059980 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Cap.

30705414 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Dig #1 Capital No Allegan Dorr 50.91

Removed and installed 50.91' of 24” x 0.375”, ERW, API5L‐X65, FBE Coated Pipe hydrotested to 1475 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30705414, Pete Pryson)

72MANUFACTURING ANOMALY near seam w




30705416 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Dig #3 Capital No Allegan Dorr 0Verification dig, no pipe cut out. 62.8 Sq.ft of coating replaced. (SAP #30705416, Pete Pryson)

Supp‐1Linear anomaly B / N/A / poss. metal loss anomaly; for validation purposes

only




30705527 30705418 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Dig #5 O&M No Allegan Leighton 8.7


518MAOP Gap

30705528 30705419 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Dig #6 O&M No Allegan Leighton 12.77


592MAOP Gap

30705520 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Dig #7 Capital No Allegan Leighton 50.74





814TRA METAL affecting seam weld / Attachm

3/15/2018



911INTERNAL CLUSTER

30705523 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Dig #10 Capital No Allegan Leighton 0Verification dig, no pipe cut out. 53 Sq.ft of coating replaced. (SAP #30705523, Pete Pryson)

Supp‐2Linear anomaly B / N/A / poss. metal loss anomaly; for validation purposes

only

30705529 30705524 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Dig #11 Capital No Allegan Leighton 50.72



30705525 L1100 ‐ KZO‐Dorr to Middleville Caledonia ‐ Dig #12 Capital No Barry Thornapple 51.31



588.18

GL‐01748 GL‐01773 L100B ‐ SAG‐Herrick to Muskegon

29015337 L100B ‐ SAG‐Herrick to Muskegon ‐ O&M Gen.

29059981 L100B ‐ SAG‐Herrick to Muskegon ‐ Capital Gen.

30977337 30977324 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #1 Capital No Isabella Vernon 60.1


38, 40, & 87INTERNAL ML CORROSION

30977338 30977326 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #2 Capital No Isabella Vernon 50.34


109ATION ANOMALY‐DENT Associated with F

30977339 30977327 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #3 Capital No Clare Grant 0Verification Dig, No pipe Cut‐out. More than 50 sq.ft of coating installed. (SAP #30977327, Mitch Loomis)


30977460 30977328 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #4 O&M Yes Clare Surrey 0Verification Dig, No pipe Cut‐out. Less than 50 sq.ft of coating installed. (SAP #30977460, Mitch Loomis)

732ANUFACTURING ANOMALY affecting seam

30977462 29059985 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #5 Capital No Clare Surrey 51.23



30977463 30977331 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #6 O&M Yes Clare Lincoln 0Verification Dig, No pipe Cut‐out and no coating replacement. (SAP #30977463, Mitch Loomis)

1833Area End Missing Data MFL‐A and XT

30977464 30977332 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #7 O&M No Clare Redding 0Verification Dig, No pipe Cut‐out and no coating replacement. (SAP #30977464, Mitch Loomis)

2653Attachment

30977465 30977333 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #8 O&M No Clare Redding 0Verification Dig, No pipe Cut‐out. Less than 50 sq.ft of coating installed. (SAP #30977465, Mitch Loomis)

2985ANUFACTURING ANOMALY affecting seam

30977466 30977334 L100B ‐ SAG‐Herrick to Muskegon ‐ Dig #9 O&M No Clare Winterfield 10

Removed and installed 10' of 36” x 0.532”, ERW, API5L‐X65, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30977466, Mitch Loomis)

3289INTERNAL CLUSTER

171.67

GL‐01749 GL‐01774 STC‐Ira Mainline 20"

29015339 STC‐Ira Mainline 20" O&M ‐ General

29059982 STC‐Ira Mainline 20" Capital ‐ General

30705401 STC‐Ira Mainline 20" Capital ‐ Dig #1 Postponed ostpone Postponed Postponed Postponed Postponed 71 Postponed

30705407 30705402 STC‐Ira Mainline 20" Capital ‐ Dig #2 Postponed ostpone Postponed Postponed Postponed Postponed 82‐84 Postponed

3/15/2018

30705403 STC‐Ira Mainline 20" Capital ‐ Dig #3 Capital No St. Clair Ira 51.96

Removed and installed 51.96ft of 20in x 0.375in, HFW, API5Lx65, FBE coated Pipe hydrotested to 1900 +/‐ 25 psig ‐ 2017 pipeline remediation (SAP#30705403 ,Walt Bies)

149INTERNAL ML CORROSION


Removed and installed 50.56 ft of 20in x 0.375in, HFW, API5Lx65, FBE coated Pipe hydrotested to 1900 +/‐ 25 psig ‐ 2017 pipeline remediation (SAP#30705404 ,Walt Bies)



Removed and installed 51.45 ft of 20in x 0.375in, HFW, API5Lx65, FBE coated Pipe hydrotested to 1900 +/‐ 25 psig ‐ 2017 pipeline remediation (SAP#30705405 ,Walt Bies)


153.97

GL‐01750 GL‐01775 L600 ‐ STC‐Clarkston to Squirrel

29059983 L600 ‐ STC‐Clarkston to Squirrel ‐ General Capital

31486828 L600 ‐ STC‐Clarkston to Squirrel ‐ Dig #1 Capital No Oakland Rose 51.16

Removed and installed 51.16 ft of 22", 0.375" W.T., X‐65, ERW, FBE Coated Pipe hydrotested to 1250 +/‐ 25 psig ‐ 2017 pipeline remediation (SAP#31486828 ,Walt Bies)

2740E0005ar longitudinal weld anomaly / with corro

31486829 L600 ‐ STC‐Clarkston to Squirrel ‐ Dig #2 Capital No Oakland Springfield 53.05


10880E0012Linear longitudinal weld anomaly

31486830 L600 ‐ STC‐Clarkston to Squirrel ‐ Dig #3 Capital Yes Oakland Independence 50.57


14760E0001ar longitudinal weld anomaly / with corro

31486831 L600 ‐ STC‐Clarkston to Squirrel ‐ Dig #4 Postponed Yes Postponed Postponed Postponed Postponed 24820E0002 Postponed



31486834 L600 ‐ STC‐Clarkston to Squirrel ‐ Dig #7 Postponed No Postponed Postponed Postponed Postponed26270E0032,26270E0033 Postponed

154.78

GL‐01751 GL‐01776 L1600 ‐ NVL‐Northville to Coolidge

29015547 L1600 ‐ NVL‐Northville to Coolidge ‐ O&M

29059984 L1600 ‐ NVL‐Northville to Coolidge ‐ Capital

30704850 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #1 Capital Yes Wayne Northville 54.84

Removed and installed 54.84 ft. of 16 in. x 0.375 in. W.T., ERW, API5L‐X52, FBE Coated Pipe, pre‐construction hydrostatically tested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation ‐ Dig (Superior order #29059668, SAP #30704850, Kevin Fielder)

151

EAM WELD DENT associated with field ben

30704851 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #2 Capital No Oakland Novi 51.5


741

SEAM WELD ANOMALY ‐ B

30704852 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #3 Capital Yes Oakland Novi 68.5


968




1085

EXTERNAL CLUSTER

3/15/2018

30704854 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #5 Capital No Oakland Novi 51.69


1124




1155

EXTERNAL SEAM WELD ML CORROSION

31167037 30704856 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #7 O&M Yes Oakland Novi 8.89



ANOMALY



1929

AM WELD ML MANUFACTURING ANOMA

30704858 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #9 Capital Yes Oakland Farmington Hills 60.02



ANOMALY

30704859 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #10 Capital No Oakland Farmington Hills 51.53


2198




2219





ANOMALY




ANOMALY




ANOMALY




ANOMALY



2457




2503 SEAM WELD DEFORMATION ANOMALY DETECTED W/ METAL LOSS associated

with gouge




ANOMALY

3/15/2018




ANOMALY

30704950 30704949 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #20 O&M Yes Oakland Farmington Hills 0Verification Dig, no pipe cut‐out. Under 50 sq. ft of coating replaced. 2017 Remediation (SAP #30704950, Kevin Fielder)





ANOMALY

30704953 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #22 Capital No Oakland Southfield 51

Removed and installed 51 ft. of 16 in. x 0.375 in. W.T., ERW, API5L‐X52, FBE Coated Pipe, pre‐construction hydrostatically tested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation ‐ Dig (Superior order #29059668, SAP #30704953, Kevin Fielder)


ANOMALY

30704954 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #23 Capital No Oakland Southfield 57.64



ANOMALY

30704956 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #24 Capital Yes Oakland Southfield 51.52



ANOMALY




ANOMALY

30704958 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #26 Capital No Oakland Southfield 50.48


3480

INTERNAL CLUSTER



3813

SEAM WELD DENT



3846




3933 & 3935 SEAM WELD ML MANUFACTURING

ANOMALY

30704983 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #30 Capital Yes Oakland Royal Oak 53.32



ANOMALY

31167140 30704984 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #31 O&M Yes Oakland Royal Oak 0Verification Dig, no pipe cut‐out. Under 50 sq. ft of coating replaced. 2017 Remediation (SAP #31167140, Kevin Fielder)

4209Attachment

30704985 L1600 ‐ NVL‐Northville to Coolidge ‐ Dig #32 Capital Yes Oakland Royal Oak 96.6


4223 & 4225 SEAM WELD ML MANUFACTURING

ANOMALY / SEAM WELD ANOMALY ‐ B

1597.49

GL‐01752 GL‐01777 L1060 ‐ STC‐St. Clair to Mt. Clemens

29015551 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ O&M

3/15/2018

29059985 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ Capital

30414402 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ Dig #1 Capital No Macomb Chesterfield 61.59

Removed and installed 61.59 ft. of 12.75 in. x 0.250 in. W.T., ERW, API5L‐X52, FBE Coated Pipe, pre‐construction hydrostatically tested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation ‐ Dig (SAP #30414402, Walt Bies)

321

DEFORMATION ANOMALY‐DENT




possible gouge



359

SEAM WELD DENT

31322617 30414406 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ Dig #4 O&M No Macomb Chesterfield 0.00Verification Dig, No pipe cut‐out. 5 sq. ft of coating replaced. (SAP# 31322617, Walt Bies) 540 & 541 EXTRA METAL

30414407 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ Dig #5 Capital Yes Macomb Chesterfield 53.55

Removed and installed 53.55 ft. of 12.75 in. x 0.250 in. W.T., ERW, API5L‐X52, FBE Coated Pipe, pre‐construction hydrostatically tested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation ‐ Dig (SAP#30414407, Walt Bies)

670 & 671

Sleeve




ANOMALY




possible gouge







ANOMALY


Removed and installed 62.02 ft. of 12.75 in. x 0.375 in. W.T., ERW, API5L‐X52, ARO Coated Pipe, pre‐construction hydrostatically tested to 1900 +/‐ 25 psig ‐ 2017 Pipeline Remediation ‐ Dig (SAP #30414413, Walt Bies)


ANOMALY

30414415 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ Dig #11 Capital No Macomb Macomb 93.38


1448 SEAM WELD DENT ripple ‐ assoc. with

field bend

30414416 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ Dig #12 Capital Yes Macomb Clinton 60.92



ANOMALY

30414417 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ Dig #13 Capital No Macomb Clinton 61.70


1785 & 1786

SEAM WELD DENT



1791‐1794 Girth Weld: MAOP Verification Cut‐out / Dent


Removed and installed 86.63 ft. of 12.75 in. x 0.375 in. W.T., ARO Coated API5L‐X52, FBE Coated Pipe, pre‐construction hydrostatically tested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation ‐ Dig (SAP #30414419, Walt Bies)

1806

INTERNAL CLUSTER

3/15/2018

31322618 30414460 L1060 ‐ STC‐St. Clair to Mt. Clemens ‐ Dig #16 O&M No Macomb Clinton 0.00Verification Dig, No pipe cut‐out. No coating replacement. (SAP# 31322618, Walt Bies) 1819 Attachment

933.98

GL‐01753 GL‐01778 L1020 ‐ NVL‐South Lyon to Northville

29015555 L1020 ‐ NVL‐South Lyon to Northville ‐ O&M

29059986 L1020 ‐ NVL‐South Lyon to Northville ‐ Capital

30081398 30081298 L1020 ‐ NVL‐South Lyon to Northville ‐ Dig #1 Capital No Oakland Lyon 0No Pipe Removed. New coating installed in excess of 50 sq. ft. (SAP #30081298, Kevin Fielder) 88

DEFORMATION ANOMALY‐DENT assoc. with field bend

30081299 L1020 ‐ NVL‐South Lyon to Northville ‐ Dig #2 Capital No Oakland Lyon 51.52

Removed and installed 51.52' of 16” x 0.375" W.T., ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30081299, Kevin Fielder)


30081321 L1020 ‐ NVL‐South Lyon to Northville ‐ Dig #3 Capital No Oakland Lyon 55.29


416 & 425INTERNAL CLUSTER

30081322 L1020 ‐ NVL‐South Lyon to Northville ‐ Dig #4 Capital Yes Washtenaw Salem 50.25



30081427 30081324 L1020 ‐ NVL‐South Lyon to Northville ‐ Dig #5 O&M No Washtenaw Salem 13.06


530 SEAM WELD DENT

30081446 30081325 L1020 ‐ NVL‐South Lyon to Northville ‐ Dig #6 Capital No Washtenaw Salem 100.34



30081449 30081327 L1020 ‐ NVL‐South Lyon to Northville ‐ Dig #7 O&M No Washtenaw Salem 10

Removed and installed 10' of 16” x 0.375" W.T., ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP # 30081449, Kevin Fielder)


280.46

GL‐01754 GL‐01779 L250 ‐ SAG‐Mt Pleasant to Zilwaukee

30217102 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ O&M Gen.

29059987 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Capital Gen.

30216956 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #1 Capital Yes Isabella Union 51.15

Removed and installed 51.15' of 16” x 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30216956, Mitch Loomis)

51 SEAM WELD ANOMALY ‐ B

30216957 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #2 Capital Yes Isabella Chippewa 70.89



30217103 30216958 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #3 Capital No Isabella Chippewa 56.6


444 ML MANUFACTURING ANOMALY near seam weld

30216959 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #4 Capital No Isabella Chippewa 180.01





554SEAM WELD ANOMALY ‐ A

30217104 30217081 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #6 Capital No Isabella Chippewa 64.5


693 DEFORMATION ANOMALY‐DENT with weld



791, 794, & 800 SEAM WELD ML MANUFACTURING ANOMALY

3/15/2018




30217084 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #9 Capital No Midland Greendale 51.34



30217105 30217085 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #10 Capital No Midland Greendale 57.11


1519DEFORMATION ANOMALY‐DENT

30217106 30217086 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #11 Capital No Midland Greendale 56.89


1571 DEFORMATION ANOMALY‐DENT with weld

30217107 30217087 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #12 Capital No Midland Ingersoll 53.5


3342 DEFORMATION ANOMALY possible gouge ‐ 0.7% ‐ Min ID = 15.39 in.

30217088 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #13 Capital No Midland Ingersoll 56.35



30217108 30217089 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #14 Capital No Midland Ingersoll 0No Pipe Removed. 124 sq. ft of new coating installed. (SAP #30217089, Mitch Loomis)

3682EXTRA METAL near seam weld

30217109 30217090 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #15 Capital No Midland Ingersoll 57.7


3699 ML MANUFACTURING ANOMALY near seam weld

30217110 30217091 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #16 Cancelled No Midland Ingersoll Cancelled Dig was assessed before so the dig was cancelled.3807

Area Start Attachment 09:00 to 03:00

30217092 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #17 Capital No Midland Ingersoll 58.18

Removed and installed 58.18' of 16” x 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP 30217092, Mitch Loomis)


30217111 30217093 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #18 Capital No Saginaw Tittabawassee 0No Pipe Removed. 54.73 sq. ft of new coating installed. (SAP #30217093, Mitch Loomis)

4811Attachment

30217112 30217094 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #19 Capital No Saginaw Tittabawassee 57.18


4839ML MANUFACTURING ANOMALY

30217113 30217095 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ Dig #20 Capital No Saginaw Tittabawassee 57.84


5113 DEFORMATION ANOMALY possible gouge ‐ 0.8% ‐ Min ID = 15.25 in.

30217115 30217097 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ MAOP Dig #22 O&M Yes Isabella Union 12.09


31MAOP GAP

30217116 30217098 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ MAOP Dig #23 Capital Yes Isabella Union 56.21


57MAOP GAP

30217117 30217099 L250 ‐ SAG‐Mt Pleasant to Zilwaukee ‐ MAOP Dig #24 Capital No Isabella Chippewa 67.12


83MAOP GAP

1383.69

GL‐01755 GL‐01780 L1800 ‐ KZO‐Schoolcraft to Plainwell

29015754 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ O&M

29059988 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Capital

30414463 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #1 Capital No Kalamazoo Prairie Ronde 65.28

Removed and installed 65.28' of 20” x 0.375" W.T., ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30414463, Pete Pryson)


3/15/2018

30414464 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #2 Capital No Kalamazoo Texas 81.48



30414465 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #3 Capital Yes Kalamazoo Texas 58.07



30414466 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #4 Capital No Kalamazoo Oshtemo 79.93


843‐847FACTURING ANOMALY Repaired by grind

30414467 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #5 Cancelled Yes Kalamazoo Oshtemo Cancelled Dig was cancelled 939 ML MANUFACTURING ANOMALY

30414468 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #6 Capital Yes Kalamazoo Oshtemo 69.38


1006‐1009Sleeve

30414469 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #7 Capital Yes Kalamazoo Oshtemo 0No Pipe Cut out. 57.57 sq. ft of new coating installed (SAP #30414469, Pete Pryson 1075 ML MANUFACTURING ANOMALY

30414470 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #8 Capital No Kalamazoo Oshtemo 78.26



30977490 30414471 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #9 O&M No Kalamazoo Alamo 30.5



30414477 30414472 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #10 O&M Yes Allegan Otsego 0Verification dig. Less than 2 sq. ft of re‐coating. (SAP# 30414477, Pete Pryson) 2066 & 2068 Extra Metal

30414478 30414473 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #11 O&M Yes Allegan Otsego 0Verification dig. Less than 2 sq. ft of re‐coating. (SAP# 30414478, Pete Pryson) 2109 Attachment

30414474 L1800 ‐ KZO‐Schoolcraft to Plainwell ‐ Dig #12 Capital Yes Allegan Otsego 68.55


2143‐2144Sleeve

531.45

GL‐01756 GL‐01781 L1800 ‐ KZO‐White Pigeon to Schoolcraft

29016067 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ O&M

29059989 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Capital

30146577 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #1 Capital No St. Joseph White Pigeon 57.44


41EXTERNAL CLUSTER

30146643 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #2 Capital No St. Joseph White Pigeon 85.05



30146649 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #3 Capital No St. Joseph Florence 80.3






30146767 30146702 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #5 Capital No St. Joseph Florence 0Verification dig. 52.33 ft of new coating installed. (SAP #30146702, Pete Pryson) 334 EXTERNAL CLUSTER




30146716 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #7 Capital No St. JosephFlorence & Constantine 1946.25



30146724 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #8 Capital No St. Joseph Fabius 95.92



30146768 30146731 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #9 Capital No St. Joseph Fabius 0Verification dig. 88.96 ft of new coating installed. (SAP #30146731, Pete Pryson) 1039 EXTRA METAL

3/15/2018

30146734 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #10 Capital No St. Joseph Fabius 69.62



30146769 30146735 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #11 O&M No St. Joseph Flowerfield 17.96


1566 SEAM WELD DENT

30146737 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #12 Capital No St. Joseph Flowerfield 72.33



30146770 30146738 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #13 Capital No St. Joseph Flowerfield 75.44


1687 & 1688 ML MANUFACTURING ANOMALY









1934SEAM WELD ANOMALY ‐ B

30146762 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #17 Capital No Kalamazoo Prairie Ronde 77

Removed and installed 77' of 20” x 0.375" W.T., ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30146762, Pete Pryson)


30146763 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #18 Capital No Kalamazoo Prairie Ronde 73.13


2086 SEAM WELD ANOMALY ‐ A

30146764 L1800 ‐ KZO‐White Pigeon to Schoolcraft ‐ Dig #19 Postponed No Kalamazoo Prairie Ronde Postponed Postponed to 2018 2149 SEAM WELD ANOMALY ‐ B

3037.3

GL‐01757 GL‐01782 L1800 ‐ KZO‐Plainwell to 30th

29016623 L1800 ‐ KZO‐Plainwell to 30th ‐ O&M

29059990 L1800 ‐ KZO‐Plainwell to 30th ‐ Capital

30120723 30120605 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #1 Capital No Allegan Watson 82.11

Removed and installed 82.11' of 20” x 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30120605, Pete Pryson)

313Attachment

30120607 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #2 Capital No Allegan Watson 81.72



30120724 30120608 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #3 Capital No Allegan Watson 52.85



30120609 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #4 Capital No Allegan Watson 75.96



30120610 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #5 Capital No Allegan Hopkins 225.5









30120613 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #8 Capital No Allegan Monterey 020" x 0.500" API5L‐X65 Petrosleeve with Trenton Wax coating over 50 Sq. ft. (SAP #30120613, Pete Pryson)

1159SEAM WELD ANOMALY ‐ A

3/15/2018

30120614 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #9 Capital No Allegan Monterey 68.88









30120617 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #12 Capital No Allegan Monterey 0Verification Dig, No pipe Cut‐out. 68 Sq.ft of coating replaced. (SAP #30120617, Pete Pryson)


30120725 30120619 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #13 O&M No Allegan Salem 0Verification Dig, No pipe Cut‐out. 0 Sq.ft of coating replaced. (SAP #30120725, Pete Pryson)

1734 EXTRA METAL near seam weld

30120726 30120720 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #14 O&M No Allegan Salem 29.62

Removed and installed 29.62' of 20” x 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation. Dig also included a 0.500" SMLS, WPHY 52 3DR 90 Segmentable elbow. (SAP #30120726, Pete Pryson)

1785 & 1787

Bend Miter Bend 7.4D ‐ 10° ‐ Right

30120727 30120721 L1800 ‐ KZO‐Plainwell to 30th ‐ Dig #15 O&M No Allegan Salem 43.2


1845 & 1847Bend Miter Bend 3.3D ‐ 21° ‐ Right

934.97

GL‐01759 GL‐01784 L100C ‐ SAG‐Airport to Herrick

29016634 L100C ‐ SAG‐Airport to Herrick ‐ O&M General

29059992 L100C ‐ SAG‐Airport to Herrick ‐ Capital General

31166470 L100C ‐ SAG‐Airport to Herrick ‐ Dig #1 Capital No Isabella Union 105.29

Removed and installed 105.29' of 16” x .0312"/0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #31166470, Mitch Loomis)

190INTERNAL CLUSTER



312N ANOMALY‐DENT associated with possib



557MANUFACTURING ANOMALY under attach



747MANUFACTURING ANOMALY under attach



891EXTERNAL CLUSTER

31166475 L100C ‐ SAG‐Airport to Herrick ‐ Dig #6 Capital No Isabella Isabella 125.06




Removed and installed 66.59 ' of 16” x 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #31166476, Mitch Loomis)











3/15/2018


Removed and installed 168.37' of 16” x 0.312"/0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #31166520, Mitch Loomis)

2348 DENT DETECTED W/ METAL LOSS ripple






2740, 5770E0007EXTERNAL SEAM WELD CLUSTER



3083EXTERNAL CLUSTER near seam weld








Removed and installed 104.22' of 16” x 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP#31166526, Mitch Loomis)












Removed and installed 120.30' of 16” x 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hyd.30rotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #31166530, Mitch Loomis)














31166535 L100C ‐ SAG‐Airport to Herrick ‐ Dig #26 Capital No Isabella Isabella 201.45Removed and installed 201.45' of 16” x 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 5633 AM WELD ML MANUFACTURING ANOMA

31166567 31166537 L100C ‐ SAG‐Airport to Herrick ‐ Dig #27 Capital No Isabella Isabella 5641 ATION ANOMALY‐DENT associated with g

31166538 L100C ‐ SAG‐Airport to Herrick ‐ Dig #28 Capital No Isabella Vernon 104.53

Removed and installed 104.53' of 16” x 0.312"/ 0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #31166538, Mitch Loomis)








3/15/2018




31166568 31166562 L100C ‐ SAG‐Airport to Herrick ‐ Dig #32 Capital No Isabella Vernon 52.79


9056FORMATION ANOMALY‐DENT possible go



4103DEFORMATION ANOMALY‐DENT

31322604 L100C ‐ SAG‐Airport to Herrick ‐ EMAT #1 Capital No Isabella Isabella 54.29





8550E0001Linear anomaly B / for validation purpose



9270E0004 & 9270E0005 Linear longitudinal weld anomaly

31322607 L100C ‐ SAG‐Airport to Herrick ‐ EMAT #4 Capital No Isabella Vernon 55.46


1.21E+15Linear longitudinal weld anomaly





Removed and installed 96.10' of 16” x 0.312"/0.375" W.T., HFW, API5L‐X52, FBE Coated Pipe hydrotested to 1400 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #31322610, Mitch Loomis)


4242.62

GL‐01760 GL‐01785 L1080 ‐ FDM‐Maple Dale to Park Rd

29016636 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ O&M

29059993 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Capital

30466435 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #1 O&M No Jackson Liberty 0 Verification Dig ‐ No Pipe Cut‐out 64 GIRTHWELD ANOMALY

30466436 30705533 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #2 Capital No Jackson Liberty 0Verification Dig ‐ No Pipe Cut‐out. > 50 sq. ft of coating replaced (SAP #30705533, Kevin Fielder) 182 ML MANUFACTURING ANOMALY

30466437 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #3 O&M No Jackson Liberty 0 Verification Dig ‐ No Pipe Cut‐out (SAP #30466437, Kevin Fielder) 371 Attachment possible patch

30466438 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #4 O&M No Jackson Summit 0 Verification Dig ‐ No Pipe Cut‐out (SAP #30466438, Kevin Fielder) 890 EXTRA METAL

30466439 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #5 O&M Yes Jackson Summit 0 Verification Dig ‐ No Pipe Cut‐out (SAP #30466439, Kevin Fielder) 1668 ML MANUFACTURING ANOMALY

30466585 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #6 Capital Yes Jackson Summit 120.3

Removed and installed 120.3' of 12.75” x 0.250" W.T., ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1500 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30466585, Kevin Fielder)

1812 & 1828ML MANUFACTURING ANOMALY

30466580 30705534 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #7 Capital Yes Jackson Summit 52.23


2066.1DENT

30466587 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #8 Capital Yes Jackson Summit 54.99


2909GIRTHWELD ANOMALY / MAOP Gap

30466582 L1080 ‐ FDM‐Maple Dale to Park Rd ‐ Dig #9 O&M Yes Jackson Summit 19.93


3383Girth Weld / MAOP Gap

247.45

GL‐01762 GL‐01787 L2500 ‐ M72 VS to Shell Processing Plant

3/15/2018

29016761 L2500 ‐ M72 VS to Shell Processing Plant ‐ O&M

29059995 L2500 ‐ M72 VS to Shell Processing Plant ‐ Capital

30574083 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #1 Capital No Kalkaska Bear Lake 73.46

Removed and installed 73.46' of 12.75” x 0.375" W.T., ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1900 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30574083, Mitch Loomis)


30574098 30574084 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #2 O&M No Kalkaska Bear Lake 34.44


349 ML MANUFACTURING ANOMALY near

seam weld

30574085 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #3 Capital No Kalkaska Bear Lake 62

Removed and installed 62' of 12.75” x 0.375" W.T., ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1900 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30574085, Mitch Loomis)


ANOMALY

30574099 30574086 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #4 O&M Yes Kalkaska Bear Lake 0No Pipe Cut out, Less than 50 sq. ft of coating (SAP #30574099, Mitch Loomis)


30574140 30574087 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #5 O&M No Kalkaska Excelsior 0No Pipe Cut out, Less than 50 sq. ft of coating (SAP #30574140, Mitch Loomis)

1073 EXTRA METAL near seam weld

30574088 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #6 Capital No Kalkaska Excelsior 58.64



ANOMALY

30574141 30574089 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #7 O&M No Kalkaska Excelsior 9.84


1694 EXTRA METAL near seam weld,

possible puddle weld

30574090 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #8 Capital No Kalkaska Kalkaska 62.33



ANOMALY




ANOMALY

30574142 30574093 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #10 O&M No Kalkaska Kalkaska 41.95



30574143 30574094 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #11 O&M No Kalkaska Kalkaska 9.17


2227 SEAM WELD DENT




ANOMALY

30574144 30574096 L2500 ‐ M72 VS to Shell Processing Plant ‐ Dig #13 O&M Yes Kalkaska Kalkaska 39

Removed and installed 39' of 12.75” x 0.375" W.T., ERW, API5L‐X52, FBE Coated Pipe hydrotested to 1900 +/‐ 25 psig ‐ 2017 Pipeline Remediation (SAP #30574144, Mitch Loomis)


ANOMALY

518.84

3/15/2018

Pipeline Integrity ‐ (Transmission)Staff Adjustments to Capital Expenditures

2016 Actual 2017 ProjectedRemaining Bridge Year Projected

12 Months Ended June 30, 2019 Projected

Company proposal $40,881,000 $45,149,000 $11,552,000 $36,014,000Disallowance ($24,092,610) ($37,293,640) ($7,965,100) ($24,831,650)Staff Proposal $16,788,390 $7,855,360 $3,586,900 $11,182,350

Pipeline Integrity Inspections and RemediationsStaff Adjustments to Operations and Maintenance

2016 Actual 2017 Projected 2018 Projected12 Months Ended June 30, 2019 Projected

Company/Staff proposal $19,973,000 $9,938,000 *Disallowance/Allowance ($455,230) $9,572,600Staff Proposal $19,517,770 $19,510,600

* S‐11.1, line 1, column (g)

Pipeline Integrity Cap Ex and O&M

A CMS Energy Company

Digitally signed by Anne M. Uitvlugt Date: 2018.04.05 08:43:54 -04'00'

1

STATE OF MICHIGAN

BEFORE THE MICHIGAN PUBLIC SERVICE COMMISSION In the matter of the application of CONSUMERS ENERGY COMPANY Case No. U-18424 for authority to increase its rates for (e-file paperless) the distribution of natural gas and for other relief. /

MICHIGAN PUBLIC SERVICE COMMISSION STAFF’S FIFTHTEENTH DISCOVERY REQUEST TO

CONSUMERS ENERGY COMPANY The Michigan Public Service Commission Staff, by its attorneys, Lauren D.

Donofrio, Amit T. Singh, Meredith R. Beidler, and Monica M. Stephens, Assistant

Attorneys General, submits the following discovery request to Consumers Energy

Company under Rule 423 of the Commission’s Rules of Practice and Procedure,1

MCR 2.309, and/or MCR 2.310:

INSTRUCTIONS A. Each discovery request must be answered separately and fully in

writing under oath, and should identify the person responsible for the answer.

B. These requests are continuing and require further and supplemental

responses if you receive or generate additional information within the scope of these

requests between the time of the original responses and the close of the record in

this case.

1 Mich Admin Code R 460.17317.

2

C. With respect to any document or communication for which you claim a

privilege, identify the document or communication, including the general subject

matter, but not the substance, state the privilege involved and also state the factual

and legal basis for the privilege.

D. Please furnish the responses to these requests within 5 business days

of the receipt of this request.

E. With respect to any question that is directed to a witness who is

unable to answer the question, please direct the question to the appropriate person

for answering.

INTERROGATORIES AND REQUEST FOR PRODUCTION OF DOCUMENTS

72. With reference to the Rebuttal Testimony of Company Witness Mary

Palkovich, pages 6-9, regarding the MAOP Standardization Engineering Analysis

Program:

a. Confirm if this program includes only the process of reviewingMAOP documentation for the Company’s pipelines and improvements to the record management system that are necessary for the reporting requirements for documentation of certain pipelines as directed in the Pipeline Safety, Regulatory Certainty, and Job Creation Act of 2011.

b. Provide a breakdown of the O&M and capital expenses relatedto the aforementioned program for each year 2017, 2018, and 2019, including appropriate breakdown of 2018 and 2019 expenditures into bridge and test year and identifying the expenditures by exhibit and line number.

c. If the aforementioned program includes testing andremediation, provide separately the O&M and capital expenses related to:

18424-ST-CE-564

3

Review of MAOP documentation Upgrades to the Company’s records management system support retrieval and reporting of MAOP documentation

Respectfully submitted, MICHIGAN PUBLIC SERVICE COMMISSION STAFF

Lauren D. Donofrio (P66026) Amit T. Singh (P75492) Meredith R. Beidler (P78256) Monica M. Stephens (P73782) Assistant Attorneys General Public Service Division 7109 W. Saginaw Hwy., 3rd Floor Lansing, MI 48917 Telephone: (517) 284-8140

DATED: March 30, 2018 18424/Discovery/15th Disc Req to CECo

18424-ST-CE-564 Page 1 of 2

Question:

72. With reference to the Rebuttal Testimony of Company Witness Mary Palkovich, pages 6-9,regarding the MAOP Standardization Engineering Analysis Program:a. Confirm if this program includes only the process of reviewing MAOP documentation

for the Company’s pipelines and improvements to the record management system thatare necessary for the reporting requirements for documentation of certain pipelines asdirected in the Pipeline Safety, Regulatory Certainty, and Job Creation Act of 2011.

b. Provide a breakdown of the O&M and capital expenses related to the aforementionedprogram for each year 2017, 2018, and 2019, including appropriate breakdown of 2018and 2019 expenditures into bridge and test year and identifying the expenditures byexhibit and line number.

c. If the aforementioned program includes testing and remediation, provide separately theO&M and capital expenses related to:• Review of MAOP documentation• Upgrades to the Company’s records management system support retrieval and

reporting of MAOP documentation

Response:

a. I confirm that the MAOP Standardization Engineering Analysis Program scope isonly to review new documentation requirements based on the Pipeline Safety,Regulatory Certainty, and Job Creation Act of 2011.

b. Per my rebuttal testimony beginning on page 8, line 22, the Company is notseeking recovery of O&M expenses related to the MAOP Compliance efforts inthis docket. The expenditures are shown below and would be on Exhibit A-57(MPP-10) with the line numbers below.

42401034

18424-ST-CE-564 Page 2 of 2

c. The amount of analysis dollars to be applied to Capital vs. O&M cannot bedetermined until the analysis is completed, currently scheduled for the end of2019.

___________________________ Mary P. Palkovich April 4, 2018


42401035

oc1804-10-231

A CMS Energy Company

April 4, 2018

Via U.S. and Electronic Mail

Lauren D. Donofrio, Esq.Assistant Attorney GeneralPublic Service Division7109 West Saginaw HighwayPost Office Box 30221Lansing, MI 48909

RE: MPSC Case No. U-18424 – In the matter of the application of Consumers Energy Company for authority to increase its rates for the distribution of natural gas and for other relief.

Dear Ms. Donofrio:

Enclosed is the Company’s response to discovery question 18424-ST-CE-563 (Supplemental).This response is being served in hard copy format only on the requesting party. The requesting party and all others will be served with the discovery response by e-mail. In an effort to save time in preparing responses to discovery requests, all responses will no longer be notarized.

In providing this response, the Company does not necessarily concede that the requested information is relevant or material to these proceedings. The Company therefore specifically reserves the right to raise objections to the introduction into evidence, through cross-examination or otherwise, of any material supplied pursuant to a discovery request.

The Company intends to supplement a prior response if it becomes aware of a relevant and material error in the response. The Company also intends to supplement a prior response if it becomes aware that there has been a significant change in circumstances unknown to the requesting party which would substantially alter a prior response in a manner which is material and relevant to this case. However, the Company does not keep prior responses under continuous review.

Sincerely,

Anne M. UitvlugtCC Hon. Suzanne D. Sonneborn, ALJ (letter and proof of service only via e-mail)

Kavita Kale, Executive Secretary (letter & proof of service via e-file)Sebastian Coppola (letter & responses via e-mail), [email protected] (& Hard C. of AG Reqs) +Excels/DisksJeffry C. Pollock (letter & responses via e-mail), [email protected] (& Hard C. of ABATE Reqs)+Excels/DisksParties of Record

General Offices: LEGAL DEPARTMENTOne Energy Plaza Tel: (517) 788-0550 CATHERINE M REYNOLDS

Senior Vice Presidentand General Counsel

Ashley L BancroftRobert W BeachDon A D’AmatoRobert A. FarrGary A Gensch, Jr.Gary L KelterbornChantez P KnowlesMary Jo LawrieJason M MilstoneRhonda M MorrisDeborah A Moss*Mir e Michael NestorMichael C. RampeJames D W RoushScott J SinkwittsAdam C SmithTheresa A G StaleyJanae M ThayerAnne M UitvlugtAaron L Vorce

Attorney

Jackson, MI 49201 Fax: (517) 768-3644

*Washington Office:1730 Rhode Island Ave. N.W.Suite 1007

Tel: (202) 778-3340 MELISSA M GLEESPENVice President, Corporate Secretary and Chief Compliance Officer

SHAUN M JOHNSONVice President and Deputy General Counsel

Bret A TotoraitisKelly M HallEric V Luoma

Assistant General Counsel

Washington, DC 20036 Fax: (202) 778-3355

Writer’s Direct Dial Number: (517) 788-2112Writer’s E-mail Address: [email protected]

Digitally signed by Anne M. Uitvlugt Date: 2018.04.04 15:58:18 -04'00'

MPSC Case No. U-18424 Exhibit S-12.66

Page 1 of 2

18424-ST-CE-563 (Supplemental)

Question:

71. With reference to the Rebuttal Testimony of Company Witness Mary Palkovich, page 24,lines 12-13, it is stated that “There is no definitive standard in the United States for HAZswhich Mr. Miller admits in his direct testimony.” Please provide a range of the typicalmeasurements the Company would expect to see for HAZs related to a typical pipeline girthweld.

Response:

As stated there are no definitive United States standards for typical HAZ measurements. There are many variables that can impact the range of dimensions for a weld heat affected zone. For example, heat input and multiple thermal cycles in an area can impact the HAZ. Considerations need to be made for metallurgical, welding and pipeline conditions to eliminate variables to reduce the risk of cracking. Consumers Energy needs to address all critical variables to minimize the risk associated with them in order to maintain a safe pipeline for the public and our customers. Due to the metallurgical complexity of HAZ, the Company recommends a technical conference with Company subject matter experts and MPSC Gas Safety Staff to align on this topic.

Heat Affected Zone (HAZ) sizes vary as heat input varies as well as the number of thermal cycles. After a rupture on a Company pipeline in November of 2017, the Company learned significantly more about HAZs because of the extensive work Consumers Energy’s Metallurgical Laboratory performed on the pipe at the ruptured location near a girth weld. Based on the Company’s learnings, the Company would expect to see a HAZ range of 1/8” to 2”, on each side of the weld, related to a typical pipeline girth weld. However, this can vary even further. The Company now believes that the HAZ is relatively small, and taking into consideration this range, along with the weld itself, the whole band is less than 6”.

The Company does not typically measure the HAZs due to the impracticality of measuring this in the field. If Staff believes it to be prudent to measure the HAZ in the field, the Company recommends this be added to the technical conference currently scheduled for April 24. Generally speaking, the Company knows HAZ are there and we move away from them. The Company does not have a lot of field data to reference for our actual HAZ sizes. The distances that we move away from HAZs do vary, also, as site conditions and pipeline conditions vary. There is a lot more to consider than just HAZ size. One significant factor is cutting back further at many of our dig sites to eliminate undue stress at the weld joint that could lead to cracking.

___________________________ Mary P. Palkovich April 4, 2018

Gas Engineering & Supply Department 42401033


Page 2 of 2





03/14/2013

Form Type: SUPPLEMENTAL

Date Submitted:

06/14/2013







2a. Street Address 1945 W.Parnall Rd.

2b. City and County Jackson Jackson

2c. State MI

2d. Zip Code 49201





4c. State MI

4d. Zip Code 49201





1.GENERAL

STEEL

PLASTICCAST/

WROUGHTIRON

DUCTILEIRON

COPPER OTHERRECONDITION

EDCAST IRON

SYSTEMTOTAL


PROTECTED


MILES OF MAIN 209.069 365.01 777.492 11969.82

7 12398.321 608.304 0 1.528 4.576 26334.127

NO. OF SERVICES 1813 23359 12964 361572 954958 0 0 172502 12158 1539326


Page 1 of 4




OVER 4"THRU 8"


TOTALS

STEEL 0 7142.292 2602.07 3433.068 127.697 16.271 13321.398


COPPER 0 1.528 0 0 0 0 1.528

CAST/WROUGHT IRON

0 19.774 321.154 219.868 44.679 2.829 608.304


PLASTIC PE .003 9933.623 1862.897 601.798 0 0 12398.321



OTHER 0 3.454 1.089 .033 0 0 4.576


TOTAL .003 17100.671 4787.21 4254.767 172.376 19.1 26334.127

Describe Other Material:



OVER 2"THRU 4"


TOTALS

STEEL 42 361941 36547 1024 151 3 399708


COPPER 16 152727 19758 1 0 0 172502

CAST/WROUGHT IRON

0 0 0 0 0 0 0


PLASTIC PE 54 842387 111912 577 27 1 954958



OTHER 7181 3080 1885 11 1 0 12158


TOTAL 7293 1360135 170102 1613 179 4 1539326



UNKNOWN PRE-1940

1940-1949 1950-1959 1960-1969 1970-1979 1980-1989 1990-1999 2000-2009 2010-2019 TOTAL


Page 2 of 4

MILES OF MAIN

115.903 800.118 548.47 3198.187 7718.403 2759.232 2285.275 5277.603 3285.866 345.070 26334.127

NUMBER OF

SERVICES17603 5305 18495 162607 302673 286906 201103 295144 219487 30003 1539326








3 3 96 95




OTHER CAUSE 117 71 701 571


PART D - EXCAVATION DAMAGE PART E - EXCESS FLOW VALUE (EFV) AND SERVICE VALVE DATA


Total Number Of Services with EFV Installed During Year: 5759

Estimated Number Of Services with EFV In the System At End Of Year:228148

* Total Number of Manual Service Line Shut-off Valves Installed During Year:

* Estimated Number of Services with Manual Service Line Shut-off Valves Installed in the System at End of Year:

*These questions only pertain to reporting years 2017 & beyond.

a. One-Call Notification Practices Not Sufficient:

b. Locating Practices Not Sufficient:

c. Excavation Practices Not Sufficient:

d. Other:







EFV data, as entered for Part E, has been provided in accordance with PHMSA instruction to report installations on single-family residential services, as well as the total number of EFVs on the distribution system.


Page 3 of 4

PART I - PREPARER

Alan Chichester,operator(Preparer's Name and Title)




Page 4 of 4





03/14/2014

Form Type: INITIAL

Date Submitted:







2a. Street Address 1945 W. Parnall Road


2c. State MI

2d. Zip Code 49201





4c. State MI

4d. Zip Code 49201





1.GENERAL

STEEL

PLASTICCAST/

WROUGHTIRON


RECONDITIONED

CAST IRON

SYSTEMTOTAL


PROTECTED


MILES OF MAIN 203.353 354.007 755.553

11940.512 12631.003 575.233 0 1.497 5.066 26466.224

NO. OF SERVICES 1732 22703 12682 357134 968233 0 0 169213 11945 1543642


Page 1 of 4




OVER 4"THRU 8"


TOTALS

STEEL 0 7098.076 2590.828 3418.75 129.699 16.072 13253.425


COPPER 0 1.497 0 0 0 0 1.497

CAST/WROUGHT IRON

0 19.091 302.279 206.903 44.131 2.829 575.233


PLASTIC PE .003 10090.732 1907.967 632.301 0 0 12631.003



OTHER 0 3.958 1.075 .033 0 0 5.066


TOTAL .003 17213.354 4802.149 4257.987 173.83 18.901 26466.224




OVER 2"THRU 4"


TOTALS

STEEL 42 357887 35155 1013 151 3 394251


COPPER 16 150444 18752 1 0 0 169213

CAST/WROUGHT IRON

0 0 0 0 0 0 0


PLASTIC PE 54 854331 113231 587 29 1 968233



OTHER 7079 3052 1803 10 1 0 11945


TOTAL 7191 1365714 168941 1611 181 4 1543642



UNKNOWN PRE-1940

1940-1949 1950-1959 1960-1969 1970-1979 1980-1989 1990-1999 2000-2009 2010-2019 TOTAL


Page 2 of 4

MILES OF MAIN

114.318 766.462 529.579 3162.666 7704.007 2754.348 2283.112 5274.117 3286.489 591.126 26466.224

NUMBER OF

SERVICES17427 5106 18071 159134 298602 285388 200471 294370 219139 45934 1543642








3 2 75 69




OTHER CAUSE 41 0 692 202












d. Other:








Page 3 of 4

PART I - PREPARER

Alan M. Chichester,Regulatory Services Engineer(Preparer's Name and Title)




Page 4 of 4





03/15/2015


Date Submitted:

08/15/2016







2a. Street Address 1945 W. Parnall Road


2c. State MI

2d. Zip Code 49201





4c. State MI

4d. Zip Code 49201





1.GENERAL

STEEL

PLASTICCAST/

WROUGHTIRON

DUCTILEIRON


EDCAST IRON

SYSTEMTOTAL


PROTECTED


MILES OF MAIN 189.790 337.537 733.135 11921.81

3 13081.537 527.869 0 1.273 4.979 26797.933

NO. OF SERVICES 1676 21778 12292 352043 986125 0 0 165680 11713 1551307


Page 1 of 4




OVER 4"THRU 8"


TOTALS

STEEL 0 7036.238 2575.781 3418.876 135.765 15.615 13182.275


COPPER 0 1.273 0 0 0 0 1.273

CAST/WROUGHT IRON

0 17.913 279.726 189.298 38.107 2.825 527.869


PLASTIC PE .003 10403.279 1998.493 679.762 0 0 13081.537



OTHER 0 3.871 1.075 .033 0 0 4.979


0 0 0 0 0 0 0

TOTAL .003 17462.574 4855.075 4287.969 173.872 18.44 26797.933




OVER 2"THRU 4"


TOTALS

STEEL 42 353252 33342 998 152 3 387789


COPPER 16 147952 17711 1 0 0 165680

CAST/WROUGHT IRON

0 0 0 0 0 0 0


PLASTIC PE 53 869221 116216 603 31 1 986125



OTHER 6996 3023 1683 10 1 0 11713


0 0 0 0 0 0 0

TOTAL 7107 1373448 168952 1612 184 4 1551307



UNKNOWN PRE-1940

1940-1949 1950-1959 1960-1969 1970-1979 1980-1989 1990-1999 2000-2009 2010-2019 TOTAL


Page 2 of 4

MILES OF MAIN

111.704 711.500 510.714 3108.873 7682.460 2751.040 2276.959 5272.775 3279.924 1091.984 26797.933

NUMBER OF

SERVICES17222 4835 17407 154812 294439 283744 199754 293584 218617 66893 1551307








2 2 60 55




OTHER CAUSE 136 74 1669 1047












d. Other:







Number of known system leaks at the end of year schedule for repair, as entered for Part C, has been modified to align with updated reporting criteria.


Page 3 of 4

PART I - PREPARER

Amanda Ward,Agent(Preparer's Name and Title)




Page 4 of 4





03/15/2016


Date Submitted:

08/15/2016







2a. Street Address 1945 W. Parnall


2c. State MI

2d. Zip Code 49201





4c. State MI

4d. Zip Code 49201



Natural Gas


Investor Owned


1.GENERAL

STEEL

PLASTICCAST/

WROUGHTIRON

DUCTILEIRON


EDCAST IRON

SYSTEMTOTAL


PROTECTED


MILES OF MAIN 186.477 332.192 716.872 11883.68

0 13448.904 504.651 0.662 5.164 27078.602

NO. OF SERVICES 1685 21632 11949 346450 1001558 163089 11566 1557929


Page 1 of 4




OVER 4"THRU 8"


TOTALS

STEEL 0 06994.838 2562.517 3404.995 141.265 15.607 13119.222


COPPER 0 0.662 0 0 0 0 .662

CAST/WROUGHT IRON

0 017.913 267.695 179.875 36.376 2.793 504.652


PLASTIC PE 0.003 10624.219 2110.358 714.323 0 0 13448.903



OTHER 0 03.98 1.151 .033 0 0 5.164


0 0 0 0 0 0 0

TOTAL .003 17641.612 4941.721 4299.226 177.641 18.4 27078.603




OVER 2"THRU 4"


TOTALS

STEEL 40 348389 32146 988 149 4 381716


COPPER 16 145968 17104 1 0 0 163089

CAST/WROUGHT IRON

0 0 0 0 0 0 0


PLASTIC PE 53 881856 119006 615 32 1 1001563



OTHER 6943 2988 1625 10 1 0 11567


0 0 0 0 0 0 0

TOTAL 7052 1379201 169881 1614 182 5 1557935

Describe Other Material: Other


UNKNOWN PRE-1940

1940-1949 1950-1959 1960-1969 1970-1979 1980-1989 1990-1999 2000-2009 2010-2019 TOTAL


Page 2 of 4

MILES OF MAIN

110.768 691.301 497.022 3072.311 7663.763 2745.424 2274.664 5268.963 3278.763 1475.624 27078.603

NUMBER OF

SERVICES17043 4676 17005 150901 290791 282089 198926 292715 218010 85784 1557940








2 2 73 68




OTHER CAUSE 139 70 1568 872












d. Other: 317







Number of known system leaks atthe end of year schedule for repair, as entered for Part C, hasbeen modified to align with updated reporting criteria.


Page 3 of 4

PART I - PREPARER

Amanda Ward,Agent(Preparer's Name and Title)




Page 4 of 4





03/14/2018

Form Type: INITIAL

Date Submitted:







2a. Street Address 1945 W Parnall Rd

2b. City and County Jackson

2c. State MI

2d. Zip Code 49201





4c. State MI

4d. Zip Code 49201



Natural Gas


Investor Owned


1.GENERAL

STEEL

PLASTICCAST/

WROUGHTIRON


RECONDITIONED

CAST IRON

SYSTEMTOTAL


PROTECTED


MILES OF MAIN 159.966 342.626 670.581

11796.975 14239.48 424.903 0 0.054 6.759 0 27641.344

NO. OF SERVICES 1478 20109 10331 329472 1051576 0 0 149316 11187 0 1573469


Page 1 of 4




OVER 4"THRU 8"


TOTALS

STEEL .012 6842.988 2537.043 3396.711 176.58 16.814 12970.148


COPPER 0 .054 0 0 0 0 .054

CAST/WROUGHT IRON

0 15.728 226.12 150.666 30.245 2.145 424.904


PLASTIC PE 0.003 11120.271 2351.477 767.73 0 0 14239.481



OTHER .693 4.375 .67 .431 .591 0 6.76


0 0 0 0 0 0 0

TOTAL .708 17983.416 5115.31 4315.538 207.416 18.959 27641.347




OVER 2"THRU 4"


TOTALS

STEEL 36 331721 28537 949 143 4 361390


COPPER 17 134416 14882 1 0 0 149316

CAST/WROUGHT IRON

0 0 0 0 0 0 0


PLASTIC PE 53 924530 126317 640 35 1 1051576



OTHER 6964 2886 1327 9 1 0 11187


0 0 0 0 0 0 0

TOTAL 7070 1393553 171063 1599 179 5 1573469



UNKNOWN PRE-1940

1940-1949 1950-1959 1960-1969 1970-1979 1980-1989 1990-1999 2000-2009 2010-2019 TOTAL


Page 2 of 4

MILES OF MAIN

107.798 616.026 459.294 2976.704 7627.376 2732.391 2264.531 5258.374 3277.396 2321.455 27641.345

NUMBER OF

SERVICES16780 4064 14704 139112 273688 277103 196455 289735 216208 145620 1573469








6 3 69 60




OTHER CAUSE 143 96 1768 979






* Total Number of Manual Service Line Shut-off Valves Installed During Year: 23

* Estimated Number of Services with Manual Service Line Shut-off Valves Installed in the System at End of Year: 70





d. Other: 61








Page 3 of 4

PART I - PREPARER

Jason Pionk,Operator(Preparer's Name and Title)




Page 4 of 4


Expires: 8/31/2020






GATHERING SYSTEMS


Report Submission

TypeINITIAL

Date Submitted





2748


CONSUMERS ENERGY CO



JACKSONCity



Natural Gas

6. RESERVED




8. RESERVED


Page 1 of 11



Expires: 8/31/2020


For the designated Commodity Group, PARTs B and D will be calculated based on the data entered in Parts L and P respectively. Complete Part C one time for all pipelines and/or pipeline facilities – both INTERstate and INTRAstate - included within this OPID.


Number of HCA Miles

Onshore 305.164

Offshore 0

Total Miles 305.164


☐Check this box and do not complete PART C if this report only includes gathering pipelines or transmission lines of gas distribution systems.

Onshore Offshore

Natural Gas 333896.46

Propane Gas

Synthetic Gas

Hydrogen Gas

Landfill Gas

Other Gas - Name:





Transmission

Onshore 38.337

2381.056 0 0 0 0 0 0 0 2419.393

Offshore 0 0 0 0 0 0 0 0 0 0


38.337

2381.056 0 0 0 0 0 0 0 2419.393


Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0 0

Subtotal Gathering

0 0 0 0 0 0 0 0 0 0

Total Miles 38.337

2381.056 0 0 0 0 0 0 0 2419.393


PART E – RESERVED


Page 2 of 11


Expires: 8/31/2020


For the designated Commodity Group, complete PARTs F and G one time for all INTERstate pipeline facilities included within this OPID and multiple times as needed for the designated Commodity Group foreach State in which INTRAstate pipeline facilities included within this OPID exist. Part F "WITHIN AN HCA SEGMENT" data and Part G may be completed only if HCA Miles in Part L is greater than zero.

PARTs F and G


☐ Interstate pipelines/pipeline facilities

☒ Intrastate pipelines/pipeline facilities in the State of MICHIGAN (complete for each State)



















b. Total number of pressure test failures (ruptures and leaks) repaired in calendar year, both within an HCA Segment and outside of an HCA Segment. 0

c. Total number of pressure test ruptures (complete failure of pipe wall) repaired in calendar year WITHIN AN HCA SEGMENT. 0




1. ECDA 173.192

2. ICDA 146.531

3. SCCDA 138.07


1. ECDA 0

2. ICDA 0

3. SCCDA 1




Page 3 of 11


Expires: 8/31/2020







1.Other Inspection Techniques n/a

b. Total number of anomalies identified by other inspection techniques and repaired in calendar year based on the operator's criteria, both within an HCA Segment and outside of an HCA Segment.

0








b. Total number of anomalies repaired in calendar year both within an HCA Segment and outside of an HCA Segment. (Lines 2.b + 3.b + 4.b.1 + 4.b.2 + 4.b.3 + 5.b)

3723





a. Baseline assessment miles completed during the calendar year. .845




Page 4 of 11


Expires: 8/31/2020







Onshore

NPS 4or less 6 8 10 12 14 16 18 20

129.087 42.194 263.423 176.513 465.431 .1 208.417 31.678 189.1

22 24 26 28 30 32 34 36 38

102.719 204.208 382.924 0 16.508 0 0 207.055 0

40 42 44 46 48 52 56 58 and over

0 .036 0 0 0 0 0 0



Offshore

NPS 4or less 6 8 10 12 14 16 18 20

0 0 0 0 0 0 0 0 0

22 24 26 28 30 32 34 36 38

0 0 0 0 0 0 0 0 0

40 42 44 46 48 52 56 58 and over

0 0 0 0 0 0 0 0


0 Total Miles of Offshore Pipe – Transmission


Onshore Type A

NPS 4or less 6 8 10 12 14 16 18 20

0 0 0 0 0 0 0 0 0

22 24 26 28 30 32 34 36 38

0 0 0 0 0 0 0 0 0

40 42 44 46 48 52 56 58 and over


Page 5 of 11


Expires: 8/31/2020


0 0 0 0 0 0 0 0


0 Total Miles of Onshore Type A Pipe – Gathering

Onshore Type B

NPS 4or less 6 8 10 12 14 16 18 20

0 0 0 0 0 0 0 0 0

22 24 26 28 30 32 34 36 38

0 0 0 0 0 0 0 0 0

40 42 44 46 48 52 5658 and over

0 0 0 0 0 0 0 0


0 Total Miles of Onshore Type B Pipe – Gathering

Offshore

NPS 4or less 6 8 10 12 14 16 18 20

0 0 0 0 0 0 0 0 0

22 24 26 28 30 32 34 36 38

0 0 0 0 0 0 0 0 0

40 42 44 46 48 52 56 58 and over

0 0 0 0 0 0 0 0


0 Total Miles of Offshore Pipe – Gathering



Unknown Pre-40 1940 - 1949 1950 - 1959 1960 - 1969 1970 - 1979

Transmission

Onshore 0 12.555 305.094 583.237 896.622 297.079

Offshore


Gathering

Onshore Type A 0 0 0 0 0 0

Onshore Type B 0 0 0 0 0 0

Offshore

Subtotal Gathering 0 0 0 0 0 0

Total Miles 0 12.555 305.094 583.237 896.622 297.079


1980 - 1989 1990 - 1999 2000 - 2009 2010 - 2019 Total Miles

Transmission

Onshore 8.146 115.948 93.387 107.325 2419.393

Offshore


Gathering


Page 6 of 11


Expires: 8/31/2020


Onshore Type A 0 0 0 0 0

Onshore Type B 0 0 0 0 0

Offshore

Subtotal Gathering 0 0 0 0 0

Total Miles 8.146 115.948 93.387 107.325 2419.393






107.824 159.711 305.02 .857 573.412


96.214 24.289 66.444 1.31 188.257


172.733 67.2 148.136 .688 388.757


412.846 191.492 92.506 .617 697.461


332.192 140.665 42.684 0 515.541


0 0 0 0 0




Onshore Totals 1174.537 585.468 655.916 3.472 2419.393

OFFSHORE Class I

Less than or equal to 50% SMYS 0


0

Steel pipe Greater than 72% SMYS 0

Steel Pipe Unknown percent of SMYS 0

All non-steel pipe 0

Offshore Total 0 0

Total Miles 1174.537 2419.393





Offshore 0 0 0 0 0


Gathering


Page 7 of 11


Expires: 8/31/2020


Onshore Type A 0 0 0 0 0

Onshore Type B 0 0 0 0 0

Offshore 0 0 0 0 0

Subtotal Gathering 0 0 0 0 0

Total Miles 1174.537 585.468 655.916 3.472 2419.393 305.164



Cause



Segments



External Corrosion 0 0 0 0 0 0 0 0

Internal Corrosion 0 0 0 0 0 0 0 0

Stress Corrosion Cracking 0 0 0 0 0 0 0 0Manufacturing 0 0 0 0 0 0 0 0Construction 0 0 0 0 0 0 0 0Equipment 0 3 0 0 0 0 0 0Incorrect Operations 1 0 0 0 0 0 0 0

Third Party Damage/Mechanical DamageExcavation Damage 0 0 0 0 0 0 0 0Previous Damage (due to Excavation Activity)

0 0 0 0 0 0 0 0


0 0 0 0 0 0 0 0

Weather Related/Other Outside ForceNatural Force Damage (all) 0 0 0 0 0 0 0 0Other Outside Force Damage (excluding Vandalism and all Intentional Damage)

0 0 0 0 0 0 0 0

Other 0 6 0 0 0 0 0 0

Total 1 9 0 0 0 0 0 0





Onshore 0Onshore Type A 0

Onshore Type B 0

OCS 0 OCS 0

Subtotal Transmission 0 Subtotal Gathering 0

Total 0


Page 8 of 11


Expires: 8/31/2020






WroughtIron

Plastic Composite1 Other2 Total Miles

Transmission

Onshore 38.3372381.05

60 0 0 0 0 0 0 2419.393


Transmission38.33

72381.0

56 0 0 0 0 0 0 0 2419.393


Onshore Type B 0 0 0 0 0 0 0 0 0 0

Offshore 0 0 0 0 0 0 0 0 0 0Subtotal Gathering

0 0 0 0 0 0 0 0 0 0

Total Miles 38.337

2381.056

0 0 0 0 0 0 0 2419.393



(a)(1) Incomplete

Records

(a)(2) Total

(a)(2) Incomplete

Records

(a)(3) Total

(a)(3) Incomplete

Records

(a)(4) Total

(a)(4) Incomplete

Records

(c)Total

(c)Incomplete

Records

(d)Total

(d) Incomplete

Records

Other1 Total

Other Incomplete

Records

Class 1 (in HCA) 5.798 .021 .366 .237 0 0 0 0 .018 0 0 0 0 0


1168.355

0 0 0 0 0 0

Class 2 (in HCA) 12.942 .274 1.023 .842 0 0 0 0 .631 .088 0 0 .147 0


570.725

0 0 0 0 0 0

Class 3 (in HCA) 142.225

8.066 36.282

21.799 0 0 0 0 94.346 5.835 0 0 8.581 0


124.149

11.845 62.746

33.68 0 0 0 0 163.336

7.146 0 0 24.251

0

Class 4 (in HCA) 1.732 .124 .251 .245 0 0 0 0 .822 0 0 0 0 0


.215 0 .219 .217 0 0 0 0 .233 0 0 0 0

Total 2026.141

20.33 100.887

57.02 0 0 0 0 259.386

13.069 0 0 32.979

0

Grand Total 2419.393





operating pressure



operating pressure


operating pressure



Page 9 of 11


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Location


ABLE



ABLE




Class 1 in HCA 5.458 .28 0 0 0 .444

Class 2 in HCA 12.69 .61 0 0 .356 1.087

Class 3 in HCA 148.658 14.653 0 0 3.428 114.695

Class 4 in HCA 1.622 .116 0 0 0 1.067

in HCA subTotal 168.428 15.659 0 0 3.784 117.293

Class 1 not in HCA 831.928 129.245 1.044 .169 1.388 204.581

Class 2 not in HCA 393.945 20.072 0 0 1.578 155.13

Class 3 not in HCA 151.8 13.239 0 0 8.644 200.799

Class 4 not in HCA .08 .038 0 0 0 .549

not in HCA subTotal 1377.753 162.594 1.044 .169 11.61 561.059

Total 1546.181 178.253 1.044 .169 15.394 678.352


1.25 MAOP > PT ≥ 1.1 MAOP Total 1.213 Total Miles Internal Inspection NOT ABLE 856.774


Grand Total 2419.393

MPSC Case No. U-18424 Exhibit S-12.73 Page 10 of 11


Expires: 8/31/2020




Jason Pionk


(989)598-5031Telephone Number

Sr. Engineering Lead

Preparer's Title

[email protected]



(517)788-2501Telephone Number

Mary P. Palkovich




[email protected]


MPSC Case No. U-18424 Exhibit S-12.73 Page 11 of 11

2

Proposed Rule Final Rule Published Rule Estimated

NPRM Publication

Estimated Final Rule

Publication Effective Date

Valve Installation & Rupture Detection

2018 Safety of Gas Transmission & Gathering Lines

2019 Enhanced Emergency Order Procedures

October 14, 2016

Standards Update - 2015 and Beyond

2018 Safety of On-Shore Hazardous Liquid Pipelines

2018 Underground Storage

January 17, 2017

State Pipeline Safety Program Certification

2018 Plastic Pipe Rule 2018

Operator Qualification, Cost Recovery, Accident & Incident Notification, and other Pipeline Safety Changes

March 24, 2017

Class Locations 2018 Operator Qualification 2018

Excess Flow Valves Beyond Single Family Homes

April 17, 2017

Exhibit S-12.74 - Page 2 of 31

Final Rules

For these rulemakings, the Notice of Proposed Rulemaking has been published and comments have

been submitted. Stakeholders are awaiting the publication of the Final Rule.


The Plastic Pipe Rule Significant Rule

NPRM Published May 21, 2015 Comments Submitted July 24, 2015

Estimated Final Rule Publication: 2018

PHMSA presented its path forward to the PHMSA Gas Pipeline Advisory Committee on June 1, 2016. The PAC provided guidance and input on the contents of the final

rule.

Related Links:

PHMSA’s Notice of Proposed Rulemaking APGA Comments on Proposed Rulemaking

4


https://www.gpo.gov/fdsys/pkg/FR-2015-05-21/pdf/2015-12113.pdf

https://www.regulations.gov/document?D=PHMSA-2014-0098-0018

The Plastic Pipe Rule

Tracking & Traceability

• Remain consistent with ASTM F2897

• Phased Implementation Phase 1 = 1 Year for Manufacturers to Adhere to Marking Standards Phase 2 = 5 Years for Operators to Implement Tracking & Traceability

5

APGA Position: 1. Agrees with the GPAC’s guidance that only markings required by ASTM F2897

should be required by federal regulation. 2. Agrees with the GPAC’s guidance that ASTM F2897 markings only need to be

legible until the pipe or component is installed. 3. Supports the GPAC’s guidance that the implementation of the regulation should

be phased in over several years to allow operators to comply.


The Plastic Pipe Rule

Plastic Pipe Installation PHMSA has indicated that some of the proposed requirements will be removed or revised

for clarity: • Backfill Requirements

• Trenchless Excavations of Mains & Services • Socket Fusion Diameter Restrictions

6

APGA Position: 1. APGA supported ensuring that backfill does not contain materials detrimental

to the pipe, but the provision, as proposed, could be interpreted vaguely. Therefore, APGA does not support the proposed requirements for backfill compaction.


The Plastic Pipe Rule Seemingly Retroactive Regulations

PHMSA has confirmed that the seemingly retroactive requirements were only intended to be prospective, including:

• Leak clamps may not be used as a permanent repair method • Protection of electrically isolated metal alloy fittings

7

APGA Position: 1. APGA supported cathodically protecting isolated metal fittings, such as with

coatings; however, does not support the proposed monitoring requirement. 2. AGA supported prohibiting the use of leak clamps for new permanent repairs;

however, agrees with PHMSA and the GPAC that it should not be a retroactive restriction.


The Plastic Pipe Rule Design Factor, Expanded Use of PA-11 &

Incorporation of PA-12 Moving forward as proposed in the NPRM.

Additionally, PHMSA will consider the retroactive application of the new PE Design Factor and other pipe diameter sizes that were not included in the NPRM.

Fusion Equipment Maintenance PHMSA will limit the requirement to requiring operators to maintain equipment in

accordance with the manufacturer’s recommended practices or with written procedures that are proven to be equivalent.

8

APGA Position: 1. AGA supported PHMSA’s modified proposal that operators follow equipment

manufacturers recommended practices, but still maintains that operators should only have to keep calibration records for the life of the pipeline.

APGA Position: 1. AGA supported this change.


Operator Qualification Significant Rule

NPRM Published: May 21, 2015 Comments Submitted: July 24, 2015

Estimated Final Rule Publication: 2018

PHMSA presented its path forward to the PHMSA Gas Pipeline Advisory Committee on June 1, 2016. The PAC provided guidance and input on the contents

of the final rule.

NOTE: PHMSA originally proposed changes to Operator Qualification in the Operator Qualification, Cost Recovery, Accident & Incident Notification and Other

Pipeline Safety Changes Proposed Rule. The balance of that rulemaking was finalized in January 2017, but did not include Operator Qualification

modifications. Related Links:


PHMSA’s Final Rule: Without Operator Qualification requirement changes

9





Operator Qualification Topics addressed in the proposed rulemaking:

1. Required Change Management Process for OQ 2. Introduction of Program Effectiveness for OQ 3. Record Keeping Requirements for Training 4. Addition of OQ for New Construction 5. Modification of the Definition of “Covered Task”

Language agreed upon during PHMSA GPAC Meeting:

10

… a covered task is an activity, identified by the operator that: 1. is performed on a pipeline facility; 2. is an operations or maintenance task including those conducted

during an emergency response, or is a construction task or an integrity management task performed on the right-of-way;

3. is performed as a requirement of this part; and 4. affects the operation or integrity of the pipeline


Operator Qualification

11

APGA Position: 1. Definition of Covered Task & OQ for New Construction: APGA has long supported

PHMSA’s efforts to include construction tasks as a covered task and under OQ. 2. Management of Change: APGA supported the incorporation of a Management of

Change process, but believed it should be limited to those operators that have more than 50 employees who perform covered tasks.

3. Program Effectiveness: APGA remains concerned that the requirement to perform program effectiveness will be administratively burdensome, particularly for small operators.

4. Training Records: APGA supported PHMSA’s proposal to require operators to provide training to ensure that any individual performing a covered task has the knowledge, skills, and abilities to perform that task. However, APGA only supports this addition if PHMSA is not proposing to add a mandatory training requirement to the OQ evaluation and re-evaluation process. Further, APGA does not support a requirement to keep records of training not performed as a part of the OQ process. APGA also believes that any requirement for training records should be on a going forward basis and not retroactive.


Safety of Gas Transmission & Gathering Lines

Significant Rule NPRM Published: April 8, 2016

Comments Submitted: July 7, 2016

GPAC Meeting #1: January 11-12, 2017 GPAC Meeting #2: June 6-7, 2017

GPAC Meeting #3: December 14-15, 2017 Next Scheduled GPAC Meeting: March 26-28, 2018

Estimated Final Rule Publication: 2019 Related Links:

PHMSA’s Advanced Notice of Proposed Rulemaking PHMSA’s Notice of Proposed Rulemaking

APGA Comments on Proposed Rulemaking GPAC Meeting #1 Information GPAC Meeting #2 Information GPAC Meeting #3 Information

12






https://primis.phmsa.dot.gov/meetings/MtgHome.mtg?mtg=121&nocache=9447



Safety of Gas Transmission & Gathering Lines • Safety of Launchers & Receivers • Record Retention Requirements • Definition of “Traceable, Verifiable, & Complete” • Definition of Transmission Line & Distribution Center • MAOP Verification • MAOP Determination • Addressing Seismicity • Material Verification • Expansion of Pipeline Assessments Outside HCAs • Moderate Consequence Areas • Repair Criteria for Pipeline Assessments • Introduction of a Definition for “Able to accommodate inspection from an ILI” • TIMP Risk Assessments & Modeling • Spike Testing & Fracture Mechanics • Corrosion Control Requirements • Management of Change • Gathering Lines • TIMP Reassessment Intervals • Continuing Surveillance after Extreme Weather Events

Topics that have been voted & approved by PHMSA’s Gas Pipeline Advisory Committee

13

Note: The results from specific topics within this

rulemaking will have tangential impact on gas

distribution operators.


Safety of Gas Transmission & Gathering Lines • Definitions of Transmission Line & Distribution Center:

Transmission line means a pipeline other than a gathering line, that:

(1) Transports gas from a gathering line or storage facility to a distribution center, storage facility or large volume customer that is not down-stream from a distribution center;

(2) Operates at a hoop stress has an MAOP of 20 percent or more of SMYS; or (3) Transports gas within a storage field Note: A large volume customer (factories, power plants, and institutional users of

gas) may receive similar volumes of gas as a distribution center.

Distribution Center means a location where gas volumes are either metered or have pressure or volume reductions prior to delivery to customers through a distribution line.

14


August 25, 2011

ANPRM Published

April 8, 2016 NPRM

Published

July 7, 2016

Comments submitted on NPRM

January 10-11, 2017

First GPAC Meeting

April 5, 2017

Comments Submitted

on first GPAC Meeting

June 6-7, 2017

Second GPAC Meeting

December 14-15, 2017

Third GPAC Meeting

March 26-28, 2018 Next

Scheduled GPAC

Meeting

June 12-14, 2018

Targeted Final GPAC

Meeting

What’s Next?


15


Effective Date of Final Rule Final Rule Publication + 6 Months = July 2019

Final Rule Publication February 2019

Office of Management and Budget Reviews & Approves Final Rule December – January 2019

Office of the Secretary of Transportation Reviews & Approves Final Rule September - November 2018

PHMSA Makes Necessary Modifications Fall 2018

PHMSA Presents Path Forward to GPAC (5+ Meetings) December 2016, January 2017, December 2017, March 2018, & June 2018

PHMSA Reviews NPRM Comments July – December 2016

Quickest Path to a Final Rule

Safety of Gas Transmission & Gathering Lines Exhibit S-12.74 - Page 16 of 31


17

APGA Position: 1. Definition of Transmission Line & Distribution Center: APGA supports PHMSA’s

proposed definition of Distribution Line if PHMSA’s intent is to exclude all pipelines operating below 20% SMYS from the definition of Transmission Line.

2. Moderate Consequence Areas: APGA supports PHMSA’s decision to not HCAs , and thus pipelines that must be incorporated into TIMP.

3. New Recordkeeping Requirements: APGA urges PHMSA to ensure that the final code language clearly states that any newly introduced recordkeeping requirements are not retroactively applied.

4. MAOP & Material Verification and Expanding Assessments Beyond HCAs: APGA urges PHMSA to limit these requirement to pipelines operating above 30% SMYS.

• PHMSA is considering limiting some of the new requirements related to MAOP and Material Verification to pipelines operating greater than 30% SMYS. That decision may come in the March or June 2018 GPAC Meetings.



18

APGA Position: 5. Corrosion Control Requirements: APGA asked that PHMSA limit some of the proposed

corrosion control requirements to transmission pipelines greater than 20% SMYS, but at a minimum ensure that the requirements to not apply to distribution pipelines.

• The GPAC ensure that the new requirements do not apply to distribution pipelines and made many of the requirements more reasonable for operators, but did not vote to limit any to pipelines operating greater than 20% SMYS.

6. Management of Change: APGA encourages PHMSA to restrict the requirements for MOC to operators that have control rooms and/or compressor stations.

• The GPAC did not vote to support this position, but did limit the changes that must be incorporated into an MOC to those that could substantially impact the integrity of the pipeline.


Additional Pending Final Regulations & Agency Actions

Safety of On-Shore Hazardous Liquid Pipelines

National Pipeline Mapping System Update

19


Proposed Rules

These are rulemakings that PHMSA has stated are in progress. The content and details of these

rulemakings remains unknown as the proposed rule has not yet been published.


Valve Installation and Minimum Rupture Detection Standards

Significant Rule NPRM with the OST for Review

Estimated NPRM publication date: 2018 Expected to cover

• Rupture detection and response time metrics, including: - Integration of ASV and RCV placement (Objective: Improve overall incident response)

Will attempt to address Legislation

• If appropriate, require ASVs, RCVs or equivalent technology on new or fully replaced transmission lines

(where economically, technically & operationally feasible)

NTSB Recommendations • Equip SCADA systems with tools to assist in recognizing and pinpointing leaks (distribution and

transmission)

21


Additional Pending Regulations / Actions

Class Location Changes – Coming SOON! Spring 2018.

Safety of On-Shore Hazardous Liquid Pipelines

Standards Update Rule – 2015 and Beyond

State Pipeline Safety Program Certification

National Pipeline Mapping System Update

Referenced in the Gas Transmission Rule NPRM or Discussed at Workshops:

Quality Management Public Awareness

LNG for Small Facilities 22


Advocacy Actions Beyond Current

Rulemakings Details are provided on APGA advocacy actions that are in progress, but are outside of specific PHMSA

rulemakings.


Farm Tap Inspections OQ, Cost Recovery, Accident & Incident Notification and Other Pipeline Safety

Changes Final Rule

Effective: March 24, 2017

New Requirement:

Related Links: PHMSA’s Notice of Proposed Rulemaking

APGA Comments on Proposed Rulemaking PHMSA’s Final Rule

Industry Comments on Deregulatory Actions (APGA Supported)

(a) This section applies, except as provided in paragraph (c) of this section, to any service line directly connected to a production, gathering, or transmission pipeline that is not operated as a part of a distribution system.

(b) Each pressure regulating or limiting device, relief device, automatic shutoff device, and associated equipment must be inspected and tested at least once every 3 calendar years, not exceeding 39 months.

24





https://www.regulations.gov/document?D=DOT-OST-2017-0069-1504

Farm Tap Inspections Post Final Rule Advocacy Actions:

1. Discussions with PHMSA On-going since the publication of the Final Rule.

2. AGA Submitted a Regulatory Impact Position Paper Highlighted the estimated annual cost impact of the new prescriptive inspection requirements and

provided a cost / farm tap comparison between DIMP and prescriptive inspection cycles. Sent to PHMSA: September 18, 2017

3. Industry Comments to the Department of Transportation on Deregulatory Actions

A suggested deregulatory action for PHMSA. Submitted to : November 9, 2017

4. Industry Comments to the Department of Transportation on Deregulatory Actions

At the December 13, 2017 PHMSA Gas & Liquid Pipeline Advisory Committee Meeting, PHMSA indicated that modifications to the new Farm Tap requirements was included in their priorities for

regulatory reform.

25


Construction Inspection Miscellaneous Changes to the Pipeline Safety Regulations Rulemaking

The Effective Dave for §192.305 is “delayed indefinitely.”

Final Rule Language:

Related Links: NAPSR Resolution on Construction Inspection


PHMSA’s Final Rule APGA Petition for Reconsideration

PHMSA’s Response to Petitions for Reconsideration

26

§192.305 Inspection: General. Each transmission line and main must be inspected to ensure that it is constructed in accordance with this subpart. An operator must not use operator personnel to perform a required inspection if the operator personnel performed the construction task requiring inspection. Nothing in this section prohibits the operator from inspecting construction tasks with operator personnel who are involved in other construction tasks.








Construction Inspection Post Final Rule Advocacy Actions:

PHMSA Created the “Construction Inspection Advisory Group” in Fall 2015 . The group was tasked with addressing concerns from industry, while meeting the goals of

the federal and state regulators. Members of the advisory group included: • PHMSA • NAPSR • APGA • AGA

• Distribution Contractors Association (DCA) The group last met in October 2015. The changes to §192.305 will not move forward

without the consensus of this advisory group.

27

APGA Petition Position: • APGA requested that PHMSA clarify that a 2-man utility crew may inspect each other’s

work and comply with the Construction Inspection requirements. • PHMSA should ensure that the Final Rule does not impact a substantial number of

small businesses.


Recently Published Rulemakings

These rules have been finalized recently.


Expanding Excess Flow Valves (EFVs) Beyond Single Family Homes

NonSignificant Rule NPRM Published: July 15, 2015

Comments Submitted: September 14, 2015 Final Rule Publication: October 14, 2015

Effective Date: April 14, 2017

Related Links: PHMSA’s Notice of Proposed Rulemaking

APGA Comments on Proposed Rulemaking PHMSA’s Final Rule

PHMSA’s Correction to Final Rule

29





https://www.gpo.gov/fdsys/pkg/FR-2016-10-21/pdf/C1-2016-24817.pdf

Excess Flow Valves (EFVs) Beyond Single Family Homes

New Requirements Include: 1. Installation of EFVs on multi-family residences and single, small commercial

customers with known customer loads not exceeding 1,000 SCFH per service,

at time of service installation.

2. Operators must notify eligible existing service line customers of their right to request an EFV be installed on their service line. Electronic notification is

allowed and include emails, website postings, and e-billing notices.

3. Installation of either a manual service line shut-off valve or an EFV for any new or replaced service line, with installed meter capacity exceeding 1,000

SCFH. They must be installed “in such a way to allow accessibility during emergencies” and are subject to “regular scheduled maintenance, as

documented by the operator and consistent with the valve manufacturer’s specification.” 30


Underground Storage Interim Final Rule

IFR Published: December 19, 2016 Comments Submitted: February 17, 2017

Industry Petition for Reconsideration Submitted to PHMSA: January 18, 2017 Petition for Reconsideration Filed to the DC Circuit Court: March 17, 2017

Effective Date: January 18, 2017 Introduces storage facilities into Pipeline Safety Regulations:

1. Incorporation of mandatory & non-mandatory provisions of API RP 1170 & 1171

2. Compliance Timeline

Notice Issued June 20, 2017: Until PHMSA addresses the petitions from industry and for one year after the publication of a final rule, PHMSA will not issue any enforcement citations to operators for failure to

meet any provisions that are non-mandatory in API RP 1170 and RP 1171.

With respect to the incorporation by reference of API RP 1170 & API RP 1171 in this section, the non-mandatory provisions (i.e. provisions containing the word “should” or other non-mandatory language) are adopted as mandatory provisions under the authority of the pipeline safety las except when the operator…

31


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