	September 30, 2019				December 31, 2018
	(Dollars in millions)
NCSA	$	7,615	38	%	$	5,649	52	%
EARC		3,782	19	%		1,378	12	%
MENA		6,464	32	%		1,834	17	%
APAC		1,632	8	%		1,420	13	%
Technology		592	3	%		632	6	%
Total	$	20,085	100	%	$	10,913	100	%

Our revenue by product offering, contract types and revenue recognition methodology was as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2019 ⁽²⁾		2018 ⁽²⁾		2019 ⁽²⁾		2018 ⁽²⁾
	(In millions)
Revenue by product offering:
Offshore and subsea	$	728	$	548	$	1,994	$	1,809
LNG		334		553		1,166		935
Downstream ⁽¹⁾		854		860		2,456		1,356
Power		205		328		853		532
	$	2,121	$	2,289	$	6,469	$	4,632

Revenue by contract type:
Fixed price	$	1,640	$	1,797	$	5,230	$	3,693
Reimbursable		324		411		733		680
Hybrid		93		10		309		134
Unit-basis and other		64		71		197		125
	$	2,121	$	2,289	$	6,469	$	4,632

Revenue by recognition methodology:
Over time	$	2,076	$	2,249	$	6,354	$	4,564
At a point in time		45		40		115		68
	$	2,121	$	2,289	$	6,469	$	4,632

For the three and nine months ended September 30, 2019, we recognized approximately $47 million and $143 million, respectively, of revenues resulting from changes in transaction prices associated with performance obligations satisfied in prior periods, primarily in our NCSA segment. Revenues reported for the 2019 periods include a $119 million settlement of claims on a substantially complete project.

For the three months ended September 30, 2018, revenues recognized from changes in transaction prices associated with performance obligations satisfied in prior periods were not material. For the nine months ended September 30, 2018, we recognized $81 million of revenues primarily resulting from changes in transaction prices during the first half of 2018 associated with performance obligations satisfied in prior periods, mainly in our APAC and MENA segments. The change in transaction prices primarily related to reimbursement of costs incurred in prior periods.

Revenues recognized during the three and nine months ended September 30, 2019, with respect to amounts included in our Advance billings on contracts balance as of December 31, 2018, were approximately $179 million and $1.5 billion.

Unapproved Change Orders and Claims—As of September 30, 2019, we had unapproved change orders and claims included in transaction prices for our projects aggregating to approximately $406 million, of which approximately $94 million was included in our RPO balance. As of December 31, 2018, we had unapproved change orders and claims included in transaction prices for our projects aggregating to approximately $428 million, of which approximately $130 million was included in our RPO balance.

Incentives—As of September 30, 2019, we had incentives included in transaction prices for our projects aggregating to approximately $214 million, primarily associated with our Cameron LNG project discussed below, of which approximately $43 million was included in our RPO balance. As of December 31, 2018, we did not have any material incentives included in transaction prices for our projects.

The amounts recorded in contract prices and recognized as revenues reflect our best estimates of recovery; however, the ultimate resolution and amounts received could differ from these estimates, which could have a material adverse effect on our results of operations, financial position and cash flow.

Our accrual of provisions for estimated losses on active uncompleted contracts as of September 30, 2019 was $131 million and included $70 million related to the Cameron LNG project. Our accrual of provisions for estimated losses on active uncompleted contracts as of December 31, 2018 was $266 million and primarily related to the Cameron LNG, Freeport LNG Trains 1 & 2, Calpine and Abkatun-A2 projects. Our Freeport LNG Train 3 project is not anticipated to be in a loss position.

Our subsea pipeline flowline installation project in support of the Ayatsil field offshore Mexico for Pemex (“Line 1 and Line 10”) and Asheville power plant project for a unit of Duke Energy Corp. were also determined to be in substantial loss positions as of September 30, 2019, as discussed further below.

For purposes of the discussion below, when we refer to a percentage of completion on a cumulative basis, we are referring to the cumulative percentage of completion, which includes progress made prior to the Combination Date. In accordance with U.S. GAAP, as of the Combination Date, we reset the progress to completion for all of CB&I’s projects then in progress to 0% for accounting purposes based on the remaining costs to be incurred as of that date.

Summary information for our significant ongoing loss projects as of September 30, 2019 is as follows:

Cameron LNG―At September 30, 2019, our U.S. LNG export facility project in Hackberry, Louisiana for Cameron LNG (being performed by our NCSA operating group) was approximately 79% complete on a post-Combination basis (approximately 93% on a cumulative basis) and had an accrued provision for estimated losses of approximately $70 million. During the three and nine months ended September 30, 2019, we recognized approximately $170 million of changes in cost estimates on this project, primarily resulting from poor labor productivity and increases in construction and subcontractor costs. The impact of this charge was partially offset by recognition during the three and nine months ended September 30, 2019 of $90 million and $200 million, respectively, of incentives related to the projected achievement of progress milestones.

Freeport LNG―At September 30, 2019, Trains 1 & 2 of our U.S. LNG export facility project in Freeport, Texas for Freeport LNG (being performed by our NCSA operating group) were approximately 96% complete on a post-Combination basis (approximately 99% on a cumulative basis) and had an accrued provision for estimated losses of approximately $8 million. During the three and nine months ended September 30, 2019, the project was negatively impacted by $42 million and $96 million, respectively, due to changes in cost estimates resulting from increases in construction and subcontractor costs. During nine months of 2019, we also recognized approximately $5 million of incentive revenues on this project.

During the three and nine months ended September 30, 2019, Freeport LNG Train 3 was negatively impacted by $9 million and $4 million, respectively, of changes in cost estimates at completion.

During the nine months ended September 30, 2019, the Freeport LNG project, as a whole, had an overall negative $95 million impact on operating margin.

Asheville Power Plant Project―As of September 30, 2019, our power project located in Arden, North Carolina (being performed by our NCSA operating group) was approximately 95% complete and had an accrued provision for estimated losses of approximately $4

million. During the three and nine months ended September 30, 2019, the project was negatively impacted by charges of $60 million and $88 million, respectively, primarily due to changes in cost estimates, partially offset by a settlement of a claim. The project is expected to be completed in the fourth quarter of 2019.

Line 1 and Line 10―As of September 30, 2019, our subsea pipeline flowline installation project in support of the Ayatsil field offshore Mexico (being performed by our NCSA operating group) was approximately 95% complete and had an accrued provision for estimated losses of approximately $2 million. During the three and nine months ended September 30, 2019, the project was negatively impacted by $3 million and $31 million, respectively, of changes in cost estimates associated with unexpected schedule extensions, resulting in additional vessel and labor costs. The project is expected to be completed in the fourth quarter of 2019.

Summary information for our significant loss projects previously reported in the 2018 Form 10-K that are substantially complete as of September 30, 2019 is as follows:

Calpine Power Project―At September 30, 2019, our U.S. gas turbine power project for Calpine (being performed by our NCSA operating group) was approximately 98% complete on a post-Combination basis (approximately 100% on a pre-Combination basis), and the remaining accrued provision for estimated losses was not significant.

Abkatun-A2 Project―At September 30, 2019, our Abkatun-A2 platform project in Mexico for Pemex (being performed by our NCSA operating group) was approximately 99% complete, and the remaining accrued provision for estimated losses was not significant.